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189-114
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, November 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 1-67 DUCK IS UNIT MPI 1-67 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/26/2025 1-67 50-029-21985-00-00 189-114-0 W SPT 9841 1891140 2460 2096 2142 2091 2103 274 276 276 277 4YRTST P Guy Cook 10/16/2025 Testing was completed with a Little Red Services pump truck and calibrated gauges. 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 1-67 Inspection Date: Tubing OA Packer Depth 334 2753 2710 2697IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC251017200638 BBL Pumped:4 BBL Returned:4.3 Wednesday, November 26, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: L DATE: Monday, October 25, 2021 Jim Re r P.I. Supervisor �Cr`ll Ftl¢I Z� SUBJECT: Mechanical Integrity Tests Mlcoip North Slope, LLC 1-67 FROM: Austin McLeod DUCK IS UNIT MPI 1-67 Petroleum Inspector Src: Inspector Reviewed B - P.I. Supry NON -CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-67 API Well Number 50-029-21985-00-00 Inspector Name: Austin McLeod Permit Number: 189-114-0 Inspection Date: 10/18/2021 Insp Num: mitSAM211018192933 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-67 - Type Inj w - TVD 9841 Tubing 2235 2245 - 2253 - 2259 - PTD 1891140 Type Test sPT'Test psi 2460 IA 1485 2912 - 2882 2877 - BBL Pumped: 1.8 1 BBL Returned: 1.9 - OA 250 _ 250 250 250 Interval 4YRTST WIF P Notes: MITIA Monday, October 25, 2021 Page I of I STATE OF ALAS AL,DA OIL AND GAS CONSERVATION COMA/SION RECEIVED ED REPORT OF SUNDRY WELL OPERATIONS 1.0 Operations AbandonDEC 15 2017 p U Plug Perforations U Fracture Stimulate U Pull Tubing Performed: Suspend ❑ Perforate U Operations shutdown f p ❑I Other Stimulate ❑ Alter Casing❑ Cha Plug for Redrill ❑ erforate New Pool CI Repair Well IIIRe-enterSusp Well III Other: ® m Fl 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Explorato 189-114 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic El ervice �6.API Number: AK 99503 50-029-21985-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0034636 DUCK IS UNIT MPI 1-67 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 12,150 feet Plugs measured 11,532 feet true vertical 10,615 feet Junk measured N/A feet 2,706, 11,301 & Effective Depth measured 11,532 feet Packer measured 11,652 feet 2,706,9,838& true vertical 10,047 feet true vertical 10,155 feet Casing Length Size MD TVD Burst Collapse Conductor 103' 30" 103' 103' N/A N/A Surface 2,498' 13-3/8" 2,498' 2,498' 5,020psi 2,260psi Intermediate 9,551' 9-5/8" 9,551' 8,418' 6,870psi 4,760psi Intermediate 1,411' 9-5/8" 10,962' 9,537' 8,150psi 5,090psi Production 10' 4-1/2" 11,666' 10,169' 8,430psi 7,500psi Liner 7,950' 7" 10,684' 9,298' 7,240psi 5,410psi Liner 1,486' 7" 12,143' 10,608' 8,160psi 7,020psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6/L-80/TC-II 11,408 9,934 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6/L-80/Mod Btc 11,666' 10,160' ZXP LTP,S 1,491 MD Packers and SSSV(type,measured and true vertical depth) Packer&WO Packer HXO SVLN See Above 1,491 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A SCA PE r4A12 N ,7ri/i 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 13,771 800 2,320 Subsequent to operation: 0 0 13,396 750 2,383 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory El Development Service ❑ Stratigraphic U Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑✓ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-498 Authorized Name: Bo York Contact Name: Taylor Wellman Authorized Title: Operations Manager Contact Email: twellmanahllcofp.com Authorized Signature: Date 12/12/2017 Contact Phone: 777-8449 Form 10-404 R ised 4/20177 / j.2 ,., g j 7 Submit Original Only ,'ly47 RBDMS (,CEC 1 5 2017 II • • Duck Island Unit Well: END 1-67 SCHEMATIC Last Completed: 3/14/2008 Mem)Alaska,LLC PTD: 189-114 SAFETY NOTE TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL KB Elev.:55.1'/BF Elev.:16.1'Doyon 15 H2S Readings average 230-260 Tree 4-1/16"CIW 13-3/8" 3,577 cu/ft Permafrost in 17.5"Hole PPM on A/L&Gas Injectors.Well Wellhead 13-5/8"FMC 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole when an Ml. 30'All CASING DETAIL 1 Size Type Wt/Grade/Conn Drift ID 7" Top643 cu/ft Class"G"in 8-1/r Hole Btm BPF 13-3/8" requires a SSV 30" Conductor N/A/N/A/N/A N/A Surface 103' N/A 13-3/8" Surface 68/NT-80/Btrs 12.415 Surface 2,498' 0.150 9-5/8" Intermediate 47/NT80/N/A 8.681 Surface 9,551' 0.0732 9-5/8" Intermediate 47/NT95HS/N/A 8.681 9,551' 10,962' 0.0732 ® 2 7" Liner 26/L-80-BTC-M 6.276 2,734' 10,684' 0.0383 7" Liner 29/L-80/Butt 6.184 10,684' 12,143' 0.0371 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TC-II 3.958 Surface 11,408' 0.0152 4-1/2" Liner 12.6/L-80/Mod Btc 3.958 11,656' 11,666' 0.0152 %. 4 JEWELRY DETAIL No Depth Item , 5 1 1,491' HXOSVLN-ID=3.813 2 2,706' Baker 7"x 9-5/8"ZXP LTP 3 2,724' Baker 7"x 9-5/8"Flex Lock Liner Hanger 6 GLM DETAIL:4-1/2"x 1"KBG2-R1 w/RK Latch and Port=0 4 3,984' ST 5:Type=DMY,Dev.=11,TVD= 3,981',4/2/2008 , !i.'': 5 5,068' ST 4:Type=DMY,Dev.=34,TVD= 4,981',4/2/2008 :r 6 5,722' ST 3:Type=DMY,Dev.=41,TVD= 5,472',4/2/2008 7 7 6,390' ST 2:Type=DMY,Dev.=40,TVD= 5,989',4/2/2008 1 8 7,038' ST 1:Type=DMY,Dev.=38,TVD= 6,495',4/2/2008 8 9 10,684' 7"x9-s/8"TIW Hydro Hanger k+ 10 11,270' X Nipple-ID=3.813 I 11 11,301' 4-1/2"x 7"Baker S Packer 4 12 11,335' X Nipple-ID=3.813 R 13 11,366' XN Nipple w/RHC-Min ID=3.725 14 11,406' 4-1/2"WLEG-Bottom @m40/ '9 15 11,652' OTIS WO Packer 4-1/2"x 7" 1) 16 11,659' OTIS 4-1/2"X Landing Nipple-ID=3.813 17 11,664' OTIS 4-1/2"XN Nogo Nipple-Min ID=3.725 18 11,665 4-1/2"WLEG-Bottom @ 11,666' PERFORATION DETAIL 12 -1:'13 END Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Date Status Size / FV 11,346' 11,366' 9,878' 9,897' 6 11/20/2017 Open 3-1/8" 9-5/8", Ili FIV 11,444' 11454' 9,967' 9,976' 4 8/26/94 Sqz. 3-3/8" 7"Marker Joint FIV 11,444' 11454' 9,967' 9,976' 6 10/24/99 Open 2" @ 11,197' FIV 11,463' 11,473' 9,984' 9,993' 6 10/24/99 Open 2" FIV 11,463' 11,473' 9,984' 9,993' 4 8/26/94 Sqz. 3-3/8" FIll 11,488' 11,496' 10,007' 10,014' 4 8/26/94 Sqz 3-3/8" TOC©11,532 ND FIll 11,488' 11,496' 10,007' 10,014' 6 10/13/97 Open 3-3/8" 11/17/2017 1v.- FIll 11,499' 11,506' 10,017' 10,023' 4 8/26/94 Sqz. 3-3/8" Top ofCarbolie Fill 11,500' 11,550' 10,018' 10,063' 6 10/13/97 Open 3-3/8" @11,57 �I r,, , m Fill 11,509' 11,525' 10,026' 10,040' 4 8/26/94 Sqz. 3-3/8" Tagged wl FIll 11,510' 11,524' 10,027' 10,040' 4 12/6/96 Open 3-3/8" 8/26/94 ~►��, ,► 15 FIll 11,527' 11,552' 10,042' 10,065' 4 8/26/94 Sqz. 3-3/8" -16 FIll 11,528' 11,540' 10,043' 10,054' 6 10/28/96 Open 3-3/8" FIll 11,540' 11,550' 10,054' 10,063' 6 4/30/99 Open 3-3/8" is TDF @11,970 Spent 17 FIll 11,605' 11,638' 10,113' 10,143' 4 6/17/95 Sqz. 3-3/8" 25'Perf G�n&1-3/4" 18 S3A4 11,702' 11,736' 10,201' 10,232' 4 2/25/90 Closed 3-3/8" Fishing1 9s Neck- Reference Log:CBL on 12/10/1989 7' : ,,. GENERAL WELL INFO WELL INCLINATION DETAIL TD=12,150 (MD)/TD 10,615'(TVD) API:50-029-21985-00-00 Max Hole Angle=42 deg.@ 9,462' PBTD=11,552'(MD)/PBTD=10,065'(TVD) Original Completion -12/4/1989 Angle at Top Perf=25 Deg.@ 11,444' Perf Adds-See Table Doyon 16 RWO -3/14/2008 Perf Add-11/20/2017 Revised By:TDF 12/11/2017 • • Hilcorp Alaska, LLC Weekly Operations Summary mar Y Well Name Rig API Number Well Permit Number Start Date End Date END 1-67 E-Line 50-029-21985-00-00 189-114 11/17/17 11/25/17 Daily Operations: 11/15/2017 -Wednesday No activity to report. 11/16/2017 -Thursday No activity to report. 11/17/2017 - Friday PT PCE 250psi LOW/2,500psi HIGH. TAG 4-1/2" MCX w/3.84" GAUGE RING AT 1,472' SLM (1,491' MD). PULL 4-1/2" MCX ser#M28 FROM HXO NIPPLE AT 1,472' SLM (1,491' MD). LOCATE WLEG AT 11,386' SLM (11,408' MD) +22' CORRECTION., TAG BTM AT 11,510' SLM (11,532' MD). DRIFT W/20' 3-1/8" DMY. GUN TO TARGET DEPTH OF 11,378' SLM (11,400' MD). 11/18/2017 -Saturday No activity to report. 11/19/2017-Sunday No activity to report. 11/20/2017- Monday WELL ON INJECTION UPON ARRIVAL. INITIAL WHP 2,400P51. PT PCE TO 250L/2,000H. RIH WITH 20'X3.13", 60 DEG, 6 SPF, EHC. SHOOT HOLES FROM 11,346' RKB TO 11,366' RKB. POOH. OOH. SECURE WELL. RD.JOB COMPLETE. TURN WELL OVER TO DSO. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 1-67 E-Line 50-029-21985-00-00 189-114 11/17/17 11/25/17 Daily Operations: 11/22/2017-Wednesday No activity to report. 11/23/2017-Thursday No activity to report. 11/24/2017-Friday No activity to report. 11/25/2017 -Saturday ***WELL ON WATER INJECTION UPON ARRIVAL*** (brush/set mcx). PT PCE 250#-LOW/2,200#-HIGH BRUSH TBG WI 4-1/2" BRUSH &3.80" G. RING TO HXO SVLN AT 1,491' MD. SET 4-1/2" MCX SSSV(M-26) IN HXO SVLN AT 1,491' MD W/EQ. DEV& 1.25" BEAN ***1 SET OF STD PKG W/O-RING***. PERFORM SUCCESFUL DRAWDOWN TEST ON SSSV. ***WELL LEFT SHUT-IN ON DEPARTURE, DSO NOTIFIED***. 11/26/2017-Sunday No activity to report. ;11/27/2017-Monday No activity to report. OF TFj • • \ I s?. THE STATE Alaska Oil and Gas ��_ ►:�-'i ®fLASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Off, p. Main: 907.279.1433 ALI�S� Fax: 907.276.7542 www.aogcc,alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 sCANNEDNOV ) 9 2017 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI 1-67 Permit to Drill Number: 189-114 Sundry Number: 317-498 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, 41110 Hollis S. French Chair DATED this 26' day of October, 2017. RBDMS - 22017 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIONOCT 17/2017 APPLICATION FOR SUNDRY APPROVALS �/© 2C`` 1 20 AAC 25.280 A 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate D. 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 ❑ 189-114 * 3.Address: 3800 Centerpoint Dr,Suite 1400 • 6.API Number: Stratigraphic ❑ Service E Anchorage Alaska 99503 50-029-21985-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462.007 Will planned perforations require a spacing exception? Yes ❑ No ❑., DUCK IS UNIT MPI 1-67 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034636 ' 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): 12,150' • 10,615' ' 11,552' 10,065' 1,300 11,552' N/A Casing Length Size MD TVD Burst Collapse Conductor 103' 30" 103' 103' N/A N/A Surface 2,498' 13-3/8" 2,498' 2,498' 5,020psi 2,260psi Intermediate 9,551' 9-5/8" 9,551' 8,418' 6,870psi 4,760psi Intermediate 1,411' 9-5/8" 10,962' 9,537' 8,150psi 5,090psi Liner 10' 4-1/2" 11,666' 10,169' 8,430psi 7,500psi Liner 7,950' 7" 10,684' 9,298' 7,240psi 5,410psi Liner 1,486' 7" 12,143' 10,608' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4-1/2" 12.6/L-80/TC-II 11,408' See Schematic See Schematic 4-1/2" 12.6/L-80/Mod Btc 11,656' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 2,724 MD/2,724 TVD, 11,301 MD/9,838 TVD&11,652 MD/10,155 TVD ZXP LTP,S Packer&WO Packer and HXO SVLN and 1,491 MD/1,491 TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q 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: Commencing Operations: 10/25/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman -rreu Authorized Title: Operations Manager Contact Email: twellman(g7hilcorp.com Of Contact Phone: 777 8449 Authorized Signature: Q°/°rh Date:COMMISSIO �� N USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑, P ,► �ELrn L(. " - L Loi acing Exception Required? Yes ❑ NogSubsequent Form Required: ,Oy0�{ APPROVED BY Approved by: 612QC( ---' COMMISSIONER THE COMMISSIONDate: t li I.'"' Gy I A 4( ,i‘r\ y•^ f 0' 3../7 Submit Form and Form 10-403 Revised 4/2017 Ap oved application is val' yf+� f to of approval. Attachments in Duplicate . • Add Perf Well: END 1-67 PTD: 189-114 llileorp Alaska,la, API: 50-029-21985-00 Well Name: END 1-67 API Number: 50-029-21985-00 Current Status: On Injection Rig: SL& E-Line Estimated Start Date: October 25, 2017 Estimated Duration: 2 days Reg.Approval Req'std? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 189-114 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 Number: Sundry/WeIIEZ Input Req'd: Yes Current Bottom Hole Pressure: 3,592psi (Based on offset well END1-55 on 08/11/16) Maximum Expected BHP: 3,592psi (Based on offset well END1-55 on 08/11/16) Max.Anticipated Surface Pressure: 1,300psi (Max recorded S/I pressure) Brief Well Summary: Endicott well 1-67 was drilled and completed in December 1989 as an Upper Sub Zones production well. From 1990—1998 there were multiple attempts to squeeze off various intervals, some were successful and some failed. In 1999 the well was converted to a WAG injector. The well received a RWO in March 2008 to repair a casing leak with a 7" tieback liner to surface. Currently the well injects into the FIll and FIV sands. • Objective: Perforate the following intervals in the table below. Run# Perf Top Perf Bottom Perf Length Formation Carrier/Charge/Note 1 11,340' 11,360' 20' FV 2-7/8" -3-1/8", 60 deg phasing, 6spf Total 20' Table 1: END 1-67 Proposed Perf Gun Runs Note: Final depths to be confirmed in "Final Approved Perf Sheet" Area of Review—Endicott DIU 1-67 (189-114) This AOR found no other wells within 1/4 mile of 1-67's entry point into the UPSZ FV Formation. / Table 2:Wells within AOR Well Name PTD Distance, Ft. Annulus Integrity 1-67 189-119 0' MIT-IA on 10/27/13 passed to 3000 psi Table 3: Completion Detail 'API Well No Permit ,1,Well ` Current Status i; ' Zonal isolation (method) WAG Injector- Cement Bond Log run on 12/10/1989 50-029-21985-00-00 189-114 1-67 Endicott Oil Pool indicates a poor quality cement job and TOC at 11,324'MD. Procedure: Slickline 1. RU SL unit and pressure test to 250psi low/2000psi high. 2. Drift to SSSV at 1,491' md. • Add Pert Well: END 1-67 PTD: 189-114 Ililtoi•v Alaska,LL, API: 50-029-21985-00 a. Brush as needed. The MCX has been installed since 07/25/10. 3. Pull SSSV from 1,491' md. 4. MU 3-1/8" drift and drift to TOC. r 5. MU 3-1/8" dummy gun and drift. °w a. Target depth to achieve is 11,400' md. 6. RD SL unit. E-Line 1. RU EL unit and pressure test to 250psi low/2000psi. 2. MU perforating tool string with 2-7/8" -3-1/8", 6spf, 60 deg phased, deep penetrating guns. 3. RIH and correlate gun run to Tie-In Log: SLB Cement Bond Log(CBL)dated 10Dec1989. Contact OE prior to perforating for final approval of tie in. a. Note any tubing pressure change in WSR. 4. RD Eline. Slicklin_e 1. RU SL unit and pressure test to 250psi low/2000psi high. 2. Set SSSV from 1,491' md. a. Description of previous SSSV set on 07/25/10: 4 1/2" MCX SER# M-26, 1.25" BEAN, X-EQ DEVICE ON SEAT. 3. RD SL unit. /'`e.5 I4A • • 0 J o_ J H a U N U U) Z > W Q o Q d a Q J o a ." E, J `moi O� LL �N E IX 2 a >w >> 2 I' ECLL `� o w d LL CO < > 2y • c_ _ g 5<NY cN N LL K w mJ J- O = wam w, ■ O o 3w w� 3 ��m�a o J 00_ 3 a - ? o Lit 2 Z `Q ra an38 0 i sc Q 2.3 ilii .- ti CO r c0 07 ID co r....„7' 4 1,0.tI M co . O1 N T Q> N. M rn CO 4.4 r N jr ,y I .,013 T 41. O � I QQ1 oft I \ co O IIT M w• N.T N` Nib r, � ' Co 0, Q rn O N.-; IN 0)a) NM "7\ N r M NgIrN T M r. E. P_ H . • Duck Island Unit Well: END 1-67 SCHEMATIC Last Completed: 3/14/2008 Meant Alaska,LLC PTD: 189-114 SAFETY NOTE TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL KB Elev.:55.1'/BF Elev.:16.1'Doyon 15 H2S Readings average 230-260 Tree 4-1/16"CIW 13-3/8" 3,577 cu/ft Permafrost in 17.5"Hole _ PPM on A/L&Gas Injectors.Well Wellhead 13-5/8"FMC 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole requires a SSV when on MI. 7" 643 cu/ft Class"G"in 8-1/2"Hole 30' CASING DETAIL 1 Size Type Wt/Grade/Conn Drift ID Top Btm BPF 13-3/8" 30" Conductor N/A/N/A/N/A N/A Surface 103' N/A 13-3/8" Surface 68/NT-80/Btrs 12.415 Surface 2,498' 0.150 9-5/8" Intermediate 47/NT80/N/A 8.681 Surface 9,551' 0.0732 2 9-5/8" Intermediate 47/NT95HS/N/A 8.681 9,551' 10,962' 0.0732 ■ 3 7" Liner 26/L-80-BTCM 6.276 2,734' 10,684' 0.0383 7" Liner 29/L-80/Butt 6.184 10,684' 12,143' 0.0371 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TC-II 3.958 Surface 11,408' 0.0152 4-1/2" Liner 12.6/L-80/Mod Btc 3.958 11,656' 11,666' 0.0152 4 WELL INCLINATION DETAIL I Max Hole Angle=42 deg.@ 9,462' Angle at Top Perf=25 Deg.@ 11,444' 5 JEWELRY DETAIL No Depth Item 6 1 1,491' FIXO SVLN-ID=3.813 2 2,706' Baker 7"x 9-5/8"ZXP LTP 3 2,724' Baker 7"x 9-5/8"Flex Lock Liner Hanger w+ GLM DETAIL:4-1/2"x 1" KBG2-R1 w/RK Latch and Port=O 4 3,984' ST 5:Type=DMY,Dev.=11,TVD= 3,981',4/2/2008 5 5,068' ST 4:Type=DMY,Dev.=34,TVD= 4,981',4/2/2008 8 46 5,722' ST 3:Type=DMY,Dev.=41,TVD= 5,472',4/2/2008 7 6,390' ST 2:Type=DMY,Dev.=40,TVD= 5,989',4/2/2008 `s 8 7,038' ST 1:Type=DMY,Dev.=38,TVD= 6,495',4/2/2008 9 10,684' 7"x 9-5/8"TIW Hydro Hanger ` 10 11,270' X Nipple-ID=3.813 9 11 11,301' 4-1/2"x 7"Baker S Packer 12 11,335' X Nipple-ID=3.813 10 t;: 13 11,366' XN Nipple w/RHC-Min ID=3.725 14 11,406' 4-1/2"WLEG-Bottom @ 11,407' MI 11, I 15 11,652' OTIS WO Packer 4-1/2"x 7" 16 11,659' OTIS 4-1/2"X Landing Nipple-ID=3.813 12 t! 17 11,664' OTIS 4-1/2"XN Nogo Nipple-Min ID=3.725 - kivi,13 18 11,665 4-1/2"WLEG-Bottom @ 11,666' s5/8„1 14 PERFORATION DETAIL 7'MarkerJoint END Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Date Status Size @11,197' FIV 11,444' 11454' 9,967' 9,976' 4 8/26/94 Sqz. 3-3/8" FIV 11,444' 11454' 9,967' 9,976' 6 10/24/99 Open 2" TOC©11,552 T FIV 11,463' 11,473' 9,984' 9,993' 6 10/24/99 Open 2" Tagged w/CalrI:'.c FIV 11,463' 11,473' 9,984' 9,993' 4 8/26/94 Sqz. 3-3/8" 8301995 c Fill 11,488' 11,496' 10,007' 10,014' 4 8/26/94 Sqz 3-3/8" Top ofCarbolite Fill 11,488' 11,496' 10,007' 10,014' 6 10/13/97 Open 3-3/8" @11,578' r Fill 11,499' 11,506' 10,017' 10,023' 4 8/26/94 Sqz. 3-3/8" Tagged 626/94w Coil :4:411.M4..,14Fill 11,500' 11,550' 10,018' 10,063' 6 10/13/97 Open 3-3/8" On t►.t 15 FIB 11,509' 11,525' 10,026' 10,040' 4 8/26/94 Sqz. 3-3/8" ',i. 16 FIll 11,510' 11,524' 10,027' 10,040' 4 12/6/96 Open 3-3/8" • 'i Fill 11,527' 11,552' 10,042' 10,065' 4 8/26/94 Sqz. 3-3/8" TOF @ 11,970'Spent `17 Fill 11,528' 11,540' 10,043' 10,054' 6 10/28/96 Open 3-3/8" 25'Perf Gun&1-3/4" 18 t Fill 11,540' 11,550' 10,054' 10,063' 6 4/30/99 Open 3-3/8" Fishing Neck- 8/21/1994 Fill 11,605' 11,638' 10,113' 10,143' 4 6/17/95 Sqz. 3-3/8" T' °firil S3A4 11,702' 11,736' 10,201' 10,232' 4 2/25/90 Closed 3-3/8" Reference Log:CBL on 12/10/1989 TD=12,150'(MD)/TD=10,615'(TVD) GENERAL WELL INFO PBTD=11,552'(MD)/PBTD=10,065'(TVD) API:50-029-21985-00-00 Original Completion -12/4/1989 Perf Adds-See Table Revised By:TDF 10/12/2017 Doyon 16 RWO -3/14/2008 • 0 Duck Island Unit f Well: END 1-67 SCHEMATIC - PROPOSED Last Last Completed: flacon;Alaska,LLC PTD: 189-114 SAFETY NOTE TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL KB Elev.:55.1'/BF Elev.:16.1'Doyon 15 H2S Readings average 230-260 Tree 4-1/16"CIW 13-3/8" 3,577 cu/ft Permafrost in 17.5"Hole 30'411 PPM on A/L&Gas Injectors.Well Wellhead 13-5/8"FMC 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole requires a SSV when on MI. 7" 643 cu/ft Class"G"in 8-1/2"Hole CASING DETAIL >; 1 Size Type Wt/Grade/Conn Drift ID Top Btm BPF 13-3/8" 30" Conductor N/A/N/A/N/A N/A Surface 103' N/A 13 3/8" Surface 68/NT-80/Btrs 12.415 Surface 2,498' 0.150 9-5/8" Intermediate 47/NT80/N/A 8.681 Surface 9,551' 0.0732 . 2 9-5/8" Intermediate 47/NT95HS/N/A 8.681 9,551' 10,962' 0.0732 7 �3 7" Liner 26/L-80-BTC-M 6.276 2,734' 10,684' 0.0383 7" Liner 29/L-80/Butt 6.184 10,684' 12,143' 0.0371 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TC-Il 3.958 Surface 11,408' 0.0152 4-1/2" Liner 12.6/L-80/Mod Btc 3.958 11,656' 11,666' 0.0152 4 JEWELRY DETAIL No Depth Item iii5 1 1,491' HXO SVLN-ID=3.813 2 2,706' Baker 7"x 9-5/8"ZXP LTP 3 2,724' Baker 7"x 9-5/8"Flex Lock Liner Hanger 11 6 GLM DETAIL:4-1/2"x 1" KBG2-R1 w/RK Latch and Port=0 4 3,984' ST 5:Type=DMY,Dev.=11,TVD= 3,981',4/2/2008 5 5,068' ST 4:Type=DMY,Dev.=34,TVD= 4,981',4/2/2008 7 6 5,722' ST 3:Type=DMY,Dev.=41,TVD= 5,472',4/2/2008 7 6,390' ST 2:Type=DMY,Dev.=40,TVD= 5,989',4/2/2008 8 8 7,038' ST 1:Type=DMY,Dev.=38,TVD= 6,495',4/2/2008 9 10,684' 7"x 9-5/8"TIW Hydro Hanger 10 11,270' X Nipple-ID=3.813 11 11,301' 4-1/2"x 7"Baker S Packer ,h 12 11,335' X Nipple-ID=3.813 " 13 11,366' XN Nipple w/RHC-Min ID=3.725 i..- 9 14 11,406' 4-1/2"WLEG-Bottom @ 11,407' 15 11,652' OTIS WO Packer 4-1/2"x 7" f 10 16 11,659' OTIS 4-1/2"X Landing Nipple-ID=3.813 A 17 11,664' OTIS 4-1/2"XN Nogo Nipple-Min ID=3.725 4 mt ► 11 wl 18 11,665 4-1/2"WLEG-Bottom @ 11,666' l'` 12 PERFORATION DETAIL to 13 END Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Date Status Size 14 FV 11,340 11,360 9,873' 9,891' 6 Future 3-1/8" 9-5/841 FIV 11,444' 11454' 9,967' 9,976' 4 8/26/94 Sqz. 3-3/8" 7"MarkerJoint�� FIV 11,444' 11454' 9,967' 9,976' 6 10/24/99 Open 2" @11,197 FIV 11,463' 11,473' 9,984' 9,993' 6 10/24/99 Open 2" FIV 11,463' 11,473' 9,984' 9,993' 4 8/26/94 Sqz. 3-3/8" TOC @11,552' T FIll 11,488' 11,496' 10,007' 10,014' 4 8/26/94 Sqz 3-3/8" Ta8/30/1995 1 Cal _ FIll 11,488' 11,496' 10,007' 10,014' 6 10/13/97 Open 3-3/8" -`1S FIll 11,499' 11,506' 10,017' 10,023' 4 8/26/94 Sqz. 3-3/8" Top ofCabolite FIll 11,500' 11,550' 10,018' 10,063' 6 10/13/97 Open 3-3/8" @11,578 'c�'1w 4.., Taggede/Coil . FIll _ 11,509' 11,525' 10,026' 10,040' 4 8/26/94 Sqz. 3-3/8" 8/26/94 ti'4y' 4 FIll 11,510' 11,524' 10,027' 10,040' 4 12/6/96 Open 3-3/8" P� ®15 II Fill _ 11,527' 11,552' 10,042' 10,065' 4 8/26/94 Sqz. 3-3/8" 16 FIll 11,528' 11,540' 10,043' 10,054' 6 10/28/96 Open 3-3/8" 17 FIll 11,540' 11,550' 10,054' 10,063' 6 4/30/99 Open 3-3/8" TOF@11,970'Spent ;-..,c FIll _ 11,605' 11,638' 10,113' 10,143' 4 6/17/95 Sqz. 3-3/8" 25'Pert Gun&1-3✓4" 18 S3A4 11,702' 11,736' 10,201' 10,232' 4 2/25/90 Closed 3-3/8" Fishing Neck- 8/21/1994 Reference Log:CBL on 12/10/1989 GENERAL WELL INFO WELL INCLINATION DETAIL TD=12,150'(MD)/TD=10,615'(TVD) API:50-029-21985-00-00 Max Hole Angle=42 deg.@ 9,462' PBTD=11,552'(MD)/PBTD=10,065'(TVD) Original Completion -12/4/1989 Angle at Top Perf=25 Deg.@ 11,444' Perf Adds-See Table Doyon 16 RWO -3/14/2008 Revised By:TDF 10/12/2017 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Wednesday,October 25,2017 P.I.Supervisor Re h �.oj27/17 SUBJECT:Mechanical Integrity Tests 4 HILCORP ALASKA LLC 1-67 FROM: Jeff Jones DUCK IS UNIT MPI 1-67 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv, NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-67 API Well Number 50-029-21985-00-00 Inspector Name: Jeff Jones Permit Number: 189-114-0 Inspection Date: 10/21/2017 ✓ Insp Num: mitJJl71025084821 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 1-67 Type Inj W 'TVD 9841 - Tubing 2200 ' 2208 ' ' 2214 • 2221 ------------ PTD 1891140 Type Test SPT Test psi 2460 - j IA I 482 2924 -I 2878 " 2865 BBL Pumped: L 3.4 BBL Returned: 3.3 OA I 250 250 260 .- 260 Interval._ 4YRTST P/F P Notes: 1 well inspected,no exceptions noted. SCANNED Et-TP ] ` ' Wednesday,October 25,2017 Page 1 of 1 • 14 `'` E D Post Office Box 244027 t� y f Anchorage,AK 99524-4027 Hilcorp Alaska,LLC J U L 3 0 20 i to 3800 Centerpoint Drive Suite 100 AOAi�d+C Anchorage,AK 99503 Phone: 907/777-8300 Fax:907/777.-8301 July 29, 2015 Commissioner Cathy Foerster SC,W5 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 I gC/ 1 / Lj Re: Duck Island Unit Well Renaming Request uest 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 "/"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/121" 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_WeliNo PermitNumber WellName WellNumber WellNumber 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/I17 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 1-47/021 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 2-12/016 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 2-18/116 2-18 ;50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 '50029219310000 1890340 DUCK IS UNIT MPI 2-22/114 2-22 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ~~,~-'//~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: []' Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] ~. of various kinds SK Other ~ COMMENTS: Scanned by: Bevedy Bre~Nathan Lowell TO RE-SCAN Notes: Complete Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: ~si NOTScanned.wpd • UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~~_ 1 ~ FILE # To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 F Anchorage, Alaska 99501 Voice (907) 279-1433 }Fax (907) 276-7542 • • bp BP Exploration (Alaska) Inc. Attn: well Integrity Coordinator, PRB -20 w} Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 Mr. Jim Regg 061 f ( f Alaska Oil and Gas Conservation Commission l 333 West 7 Avenue Anchorage, Alaska 99501 01) 1 (O Subject: Corrosion Inhibitor Treatments of Endicott Row 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 1 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 • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Endicott Row 1, Date: 09/24/2010 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 END1 -01 /J -19 1880370 50029218010000 1.5 0.3 0.5 9/2/2010 0.85 9/23/2010 END1 -03 / P -16 1951500 50029226018000, 4.0 3.5 0.5 9/2/2010 5.10 , 9/23/2010 END1 -05 / 0 -20 1861060 50029216050000 0.3 NA 0.3 NA 1.70 9/23/2010 END1 -09 / L -21 1970290 50029217430100 6.0 5.0 0.5 8/28/2010 3.40 9/23/2010 END1 -15 / P -25 1930560 50029223610000 4.0 3.0 0.5 , 9/2/2010 6.80 9/23/2010 END1 -17 /1-17 1961990 50029221000100 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1- 19/1 -18 1950930 50029225690000 7.0 9.3 0.5 9/2/2010 4.25 9/23/2010 END1 -21 / K -25 1900020 50029220050000 2.5 1.5 0.5 9/2/2010 1.70 9/23/2010 END1 -23 / 0 -15 1941280 50029225100000 12.0 12.5 0.5 9/2/2010 1.70 9/23/2010 END1 -25 / K -22 1970750 50029217220100 5.0 1.5 0.5 9/2/2010 5.10 9/23/2010 END1 -27 / P -20 1870090 50029216930000 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -29 1M-25 1861810 50029216690000 2.0 1.3 0.5 9/2/2010 1.70 9/23/2010 END1 -31 / M -21 1950720 50029225620000 5.0 1.8 0.5 9/2/2010 13.60 , 9/23/2010 END1 -33 / L -24 1982550 50029225770200 1.5 0.3 0.5 9/2/2010 3.40 9/23/2010 END1 -35 / 0-25 1861840 50029216720000 8.0 4.8 0.5 9/2/2010 3.40 9/23/2010 END1 -37 / P -24 1870900 50029217480000 0.5 NA 0.5 NA 4.25 9/23/2010 END1 -39A / N -16 2061870 50029218270100 0.5 NA 0.5 NA 6.80 , 9/23/2010 END1 -41 / 0-23 1870320 50029217130000 8.0 5.2 0.5 9/2/2010 4.25 9/23/2010 END1 -43 / P -26 1881050 50029218640000 2.0 0.5 0.5 9/2/2010 3.40 9/23/2010 END1 -45 / 0-26 1891240 50029219910000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -47A / M -20 1972030 50029216250100 1.0 0.1 0.5 9/2/2010 3.40 9/24/2010 END1 -49 / P -21 1880780 50029218410000 1.0 0.8 0.5 9/2/2010 3.40 . 9/24/2010 END1 -51 / V -20 1921190 50029223040000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -53 / 0-20 1941120 50029225010000 9.0 4.2 0.5 9/2/2010 1.70 9/24/2010 END1 -55 / R -25 1880210 50029217880000 1.3 0.1 0.5 9/2/2010 1.70 9/24/2010 END1 -57 / R -23 1881140 50029218730000 3.0 1.3 0.5 9/2/2010 5.10 9/24/2010 END1 -59 / 0-24 1960220 50029226440000 3.0 1.3 0.5 9/2/2010 0.85 9/24/2010 END1 -61 / 0-20 1941420 50029225200000 8.0 6.8 0.5 , 9/2/2010 2.55 9/24/2010 END1 -63 / T -22 1890060 50029219050000 8.0 4.1 0.5 9/2/2010 2.55 9/24/2010 END1 -65A / N -27 2032120 50029226270100 8.0 5.8 0.5 9/2/2010 3.40 9/24/2010 - END1 -67 / T -20 1891140 50029219850000 0.5 NA 0.5 NA 1.70 9/24/2010 END1 -69 / V -19 1900290 50029220200000 15.0 10.3 0.5 9/2/2010 0.85 9/24/2010 AOGCC MITIA Forms for 5-21 021540), S-217 (2070950), L-115 (2000), L-215.(.... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] tzl~j~~ Sent: Tuesday, December 01, 2009 1:53 PM 1 ~(~ To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: NSU, ADW Well Integrity Engineer; MPU, OMS Facility Coordinator; MPU, OMS Field Coordinator Subject: AOGCC MITIA Forms for S-215 (2021540), S-217 (2070950), L-115 (2011400), L-215 (2051270), L-216 (2040650), Z-02A (1960430), Z-25 (1881590), 1-67/T-20 (1891140), MPF- 91 (2051100), MPS-10A (2051250), B-22A (2001570) Attachments: MIT PBU S-215 S-217 11-17-09.x1s; MIT PBU L-115, L-215, L-216 11-30-09.x1s; MIT PBU Z- 02A, Z-25 11-30-09.x1s; MIT MPU MPF-91 11-06-09.x1s; MIT END 1-67(T-20) 11-21-09.x1s; MIT MPU MPS-10A 11-06-09.x1s; MIT PBU B-22 11-13-09.x1s Jim, Tom, and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: S-215 (PTD #2021540) S-217 (PTD #2070950) L-115 (PTD #2011400) L-215 (PTD #2051270) L-216 (PTD #2040650) Z-02A (PTD #1960430) 1881590) ,1-67/T-2~~-, (P_, TD #1891140) MPF-91 (PTD #2051100) MPS-10A (PTD #2051250) B-22A (PTD #2001570) ~~,~~~ ~ «MIT PBU S-215 S-217 11-17-09.x1s» «MIT PBU L-115, L-215, L-216 11-30-09.x1s» «MIT PBU Z-02A, Z- 25 11-30-09.x1s» «MIT MPU MPF-91 11-06-09.x1s» «MIT END 1-67(T-20) 11-21-09.x1s» «MIT MPU MPS-10A 11-06-09.x1s» «MIT PBU B-22 11-13-09.x1s» Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: {907) 659-5102 Pager: {907) 659-5100 x3154 12/4/2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. ~~ ~ ~ 2~ ~~ ~~ FIELD /UNIT /PAD: Endicott / Endicott /Row 1 l DATE: 11 /21 /09 OPERATOR REP: Anna Dube AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 1-67/T-20 Type Inj. W TVD 9 837' Tubing 2,450 2,500 2,480 2,460 Interval 4 P.T.D. 1891140 Type test P Test psi - 2459 Casing 50 4,000 3,920 3,900 P/F P Notes: MIT-IA pre-MI, submitted as UIC 4-yr compliance OA 480 500 500 500 Declined to witness by Chuck Scheve Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA TYPEINJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 2009-1121_MIT_DIU_1-67.x1s Page 1 of 1 • Maunder, Thomas E (DOA) From: Hubbie, Terrie L [Terrie.Hubble@bp.com] Sent: Wednesday, May 28, 2008 3:21 PM To: Maunder, Thomas E (DOA) Cc: Aras.Worthington@bp.com; Stewman, Sandra D Subject: RE: End 1-67/T-20 (189-114} ~ Hmmm... I have reviewed this one and yes, I do agree that on the diagram more perf zones should be shown with a"C" for closed. That would be everything below the Cement Cap Top at 11534'. As for what is listed on the 10-404 for the perF intervals, we usually list the range (top to bottom) for ali perfs that have not been cemented (squeezed of~. I fee! that it wouldn't be much of a job to open those lower perFs up. To me the perfs are Open, but isolated and the diagram helps to make that clear. It would be even more clear if the 'C' indication was entered where appropriate. Since Section 11, doesn't specify Open Perf's only, we have elected to continued to show those perfs that are isolated but not cemented off as "Open". A couple af the intervals are divided by the Cement Cap depth, making it harder to clearly show which intervals are Closed and which are Open. If you would like to change the Perf Depth info, I guess you could make it 11444' - 11534' (9966' - 10048' TVD). Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Sunday, May 25, 2008 1:50 PM To: Worthington, Aras J Cc: Hubble, Terrie L ;~ ~~ Subject: End 1-67J1"-20 (189-114) ~ ~ ,° a ~~ ~.'~, ~ - ~ °~`~~'°~ ~~:~,,;~ ~}~~~~. , ... .x Aras, I am reviewing the 404 for the work recently completed in March. On the drawing, aren't there a lot more perf "closed" than shown? It also seems appropriate that only the open perforations should be shown in block 11. Call or message with any questions. Tom Maunder, PE AOGCC 5/30/2008 . STATE OF ALASKA ~/ _p~' ALAS~L AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~C~~~~~~ APR Y Y 2008 Alaska Oil & Gas Cons 1. Operations Performed: A~CI10C~ @ ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change App~oved Program ^ Operation Shutdown ^ Perforate ^ Time E~ension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 189-114 ~ 3. Address: ~ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21985-00-00~ 7. KB Elevation (ft): 55 1' - 9• Well Name and Number: ~ . END 1-67 / T-20 8. Property Designation: 10. Field / Pool(s): , ADL 034636 - Endicott Field / Endicott Pool 11. Present well condition summary Total depth: measured 12150 ~ feet true vertical 10614 ~ feet Plugs (measured) 11534' Effective depth: measured 11534 feet Junk (measured) N/A true verticat 10048 feet Casing Length Size MD ND Burst Collapse Structural Conductor 103' 30" 103' 103' Surface 2498' 13-318" 2498' 2498' S020 2270 Intermediate 10962' 9-5/8" 10962' 9536' 6870 4760 Production Liner 1730' 7" 2695' - 12143' 9297' - 10607' 9690 7820 Perforation Depth MD (ft): 11444' - 11736' Perforation Depth TVD (ft): 9966' - 10232' 4-1/2", 12.6# L-80 11408' & Tubing Size (size, grade, and measured depth): (11655' - 11668') Packers and SSSV (type and measured depth): ~~~ x 4- 1 /2" Baker S-3 packer; 1 t305'; 7" Otis'WD' packer 11655' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Pull tubing from 10748'. Run 7" (26#, L-80, TC-II) tieba ck to 2695'. Cement w/ 229 bbls Class 'G' (1285 cu ft/ 1099 sx). Clean out and run new 4-112", 12.6# L-80 / TCII tubin . 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bb! Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 11280 300 2442 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ~ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ^ Oil ^ Gas ^ WAG ^ GINJ ~ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or PUA if C.O. Exempt: Contact Aras Worthington, 564-4102 308-009 Printed Name David Reem Title Engineering Team Leader Prepared By Name/Number: Sig ture Phone 564-5743 Date - Terrie Hubble 56a-a628 Form 10-404 Revised 04/2006 ~~~ ~~. f~=}~ ~~ f~ ~pQ~ ~...~ E ~, ~ t.:~ 4 ~ ~I ~ ~. G"' `'Submit Original Only l~ tSSlpP TREE: 4-1/16" / 5000 psi i~n t Axelson Actuator WELLHEAD: 13-5/8" / SODO psi / ~MC ~~D~ ~~~ • ~~ ~~ ~ ~~ R.T. ELEV = 55.1' B.F. ELEV = 16.1' MAX. DEV. = 41:48 9400' MD 13-3/8", 68#/ft, L-80, Btrs Csg 2498' -~ ~ AAI~J fI~ - 3.7~5" a~,"} }CXXX' ~~1f~~i Xf~ NI~PLE 9-5/8", 47#/ft NT80S XO to NT95HS 9551' -~ Fully Cemented 3-10-2008 7", 26#/ft, BTC-MOD, L-80 TOP OF 7", 29# LINER ~nr c~ 9-5/8", 47#/ft, NT95HS, NSCC 10962' F~IiF{7F2AT[CxU SUMMAFZY k~ t_CJ(s: CB~ C~N'12/1f3189 AF~K3LE AT TOF'F~F: ??? ~$ 1144~` te: Reter ta Roduct~n f~, tar histnrical perf dar SIZ[ S~ Ih~S'~72VAL '" C7ATE 3-3/8" 4' 1 1444 - i 1454 C3 3-3t~4" ++ ' 1'1483 - i~ 473 ' C7 3-3f~" 4 19 d48 - 91496 [} 3-3i~" 4 99SQO=~75~5 ~J 3-318" +l 'I15Q8 - 11S~2S CJ 3-3t8" 4 11527 -11552 E? 3-3f8" d 916p5 - 91638 q 3-3/8" 4 19510-'i'1524 U 3-3l8" 4 11528 - 115A0 ~ 2-7l8" 6 11540 - 19 55D ' C7 3-3/8" 4 '1'17d'2 - 1A736 C i.. ntx: c~ = vren ~ ~ a ~~v~cv i PBTD 12050' 7", 29#/ft, SM-110, ~ (~ ~ SSSV LANDING NIPPLE 1491' v I HES HXO (3.813" I.D.) -~ I I W/SSSV MIN I.D. ?" •4-1/2", 12.6#/ft, L-80, TCII 26~~° 7" x 9 5f8"` ZXP L1NER FKR t~AS tl !FF l4:~ANC~E~S tlfB6-2t 5 M~ TVC7 , ....... YLV ,~T. LAT PORT CJATE 5 33.k~ :v£~1 L?:~{ ~2K D (73d13~9 4 S!3!;~i n~t31 , C~hiY RK CJ d,~it;3;i~~3 3 ''~iT1 3~lil' CJF~'' RK 0 tt~t€`„fGti 2 ga;?t3?l ~it3~s?? Caht4' RK 4 C1~tt37t3~s 1' Ii3~~ a"~t~~' (JI~Y RK 0 Ct~it.~ria8 11 ~~fl° ~"~d-112° F~S X h7Y? !D= 3.813'~ ~138I~' ~-^~7" x S i/'1" ~-3 R(R, Y7 ~ 3.ti~„ ~1~~~' a-~tz~~~~xn~iP, o=~.aa~t~ ~ 13~6' a-~ rz~° w~s xr~t ~v~?, ~_:~. rzs~~ ~a1~Q!8" ~-~t2" V~LEU 11197" n9AR~c~ ii~:'S4' CEMEMCAFTC~fG~lCdGt~S~ ~~ "" 7" OfiIS 'WL7" PKR 11655 4-1/2"'X' NIPPLE L~ OTIS (3.813" I.D.) ~ 2~ `/ 4-1/2" 'XN' NIPPLE 11666' OTIS (3.725" I.D.) 11fiFA ~- 4-1/2" WLEG ~-3-3/8" SPENT PERF GUN (25' LONG). 1-3/4" FISHING NECK TAGGED PBTD @ 11970' WLM 8/21/94 [7ATE REV BY C~"JMMHJIS f3ATE R~V 6Y CC~Mt~AET~IS 777 OR~~'tNRL C~MPI. SJ3tt4l48 Di6 Ft4Nt) 03It7l08 ITLN GC7RRF~FKJt~.fi 43l2?(48 ~,lAliLFi TALLY CQRR~TY~M1}SS HY1E}~(Y:)7T U(~Et WELI,: 1-671 T-2Q FERMIfi Na: 189114D R PI Nc3 50-02~-21985-~Q SEC T hi F2 E BP FXp€orat~on (Ataskaj Bigital ~~Vell File Page 1 of 2 ~ ~ Well: 1 67 Well History Well Date Summary END1-67 2/3/2008 T/I/0= 800/150/0 Assist Slickline with lubricator pressure test. Final WHP=800/150/0. casing valves open to gauges. END1-67 2/3/2008 ~'" WELL SHUT IN ON ARRIVAL"* RAN 3.625" CENT. W/ 1.75" TO 11.350' SLM. (DID NOT S/Dl ~i~' .80 4.5' T L. W/ PETRODAT GAUGES. LOCATE TTL. C~? 10715' SLM (-28' CORR) SBHPS IN PROGRESS "'CONT. WSR ON 02-04-08"' END1-67 2/4/2008 **'CONT. WSR FROM 02-03-08"* RAN SBHP SURVEY MAKING 15 MIN STOPS @ 11,209' MD,11321' MD & 11,209' MD PETREDAT REPORTED GOOD DATA. *"LEFT WELL S/I NOTIFY DSO*" END1-67 2/5/2008 Assist E-line - MIT T to 3500 psi, MIT OA to 2000 psi '*' Job continued on 02/06/08 WSR ~*" END1-67 2/5/2008 ""WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O: 825/150/0"" SET FASDRILL AT 10695 FT MID ELEMENT. IN OMPLETE. CONTINUED ON 06-FEB-2008*'" END1-67 2/6/2008 "" Job continued from 02/05/08 WSR "" T/I/O = 200/150/0 Temp = S/I - Assist E-line, MIT T FAILED to 3500 psi, MIT OA PASSED to 2000 si (RWO prep) - Tbg is fluid packed. Pressured up Tbg to 3500 psi w/~'~6GIs 35~`FTeseT g ost psi in 1st 15 min and 60 psi in 2nd 15 min for a total loss of 120 psi in 30 min test. Bled Tbg to starting pressure. Pressured up OA to 2000 psi w/3.75 bbls 35"F diesel. OA lost 10 psi in 1 st 15 min and 0 psi in 2nd 15 min for a total loss of 10 psi in 30 min test. Bled OA to starting pressure. FWP's = 180/100/0 "" Casing valves open to guages, tags hung, DSO notified of well status "' END1-67 2/6/2008 "'"JOB CONTINUED FROM 05-FEBRUARY-2008"" SET 4.5" FASDRILL PLUG WITH MID-ELEMENT AT 10695'. OVERALL PLUG LENGTH = 28.92". CUT TUBWG AT 10 634 FT MD USING 3.65" SLB POWER CUTTER. WELL LEFT SHUT-IN //O: 100 150 0. *"JOB COMPLETE'** END1-67 2/9/2008 Circ-out TxIA ( Pre RWO) Road to location, standby for hard line crew to install check valve on jumper from End1-67 to End 1-65 "" Job continued on 2/10/08 WSR"" END1-67 2/10/2008 "' Job continued from 2/9/08 WSR"' T/I/0= 200/140/10 Temp= S/I Circ-Out (Pre RWO) Pumped 5 bbls meth followed by 556 bbls 1% KCL and 1145 bbls 9.8 NaCI down Tbg thru jet cut at 10634' taking returns up IA thru jumper to END1-65. Pumped 30 bbls diesel to freeze protect TxIA. U-tube TxIA. Freeze protect surface lines. Final WHP's= 0/0/0 "Annulus casing valves left open" END1-67 2/20/2008 T/I/0=0/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (INCONCLUSIVE). Pre RWO. PPPOT-T: Stung into test port to check pressure (50 psi), bled to 0 psi. Functioned LDS, replaced 1 broken LDS, the rest moved but are tight, no sign of bent or broken pins. Pumped through void until clean returns achieved. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Test void packed with plastic. Functioned LDS, all moved freely with no sign of bent or broken pins. Unable to pump through void. END1-67 2/29/2008 T=O; Pull 4-1/16 CIW "H" BPV thru tree; 1-2' ext. used, tagged @ 102'; "'Complete"' (BesUWortham) END1-67 3/1/2008 T=O; Pull 4 1/16" GIW H TWG THRU STAGK 2- 5'. 1-3' and 5' centralizer used, tag at 116": RKB 22.93 ; "` COMPLETE'*' ( BesUWortham) r~ ~ END1-67 3/29/2008 T/I/0= 0/0/0; Pulled 4-1/16" CIW "H" BPV #111 thru tree; 1-2' ext. used,tagged C~ 102"; *"Complete"* (Best/Wortham) END1-67 4/2/2008 T/I/O = 20/0/0 - Assist Slickline, MIT IA PASSED to 2750 psi (RWO) Pumped 55 bbls 30`F diesel to pressure up IA to 2750 psi. IA lost 30 psi in 1 st 15 min and 0 psi in 2nd 15 min for a total loss of 30 psi in 30 min test. Bled IA to starting pressure. Bled back -5 bbls fluid. FWP's = 20/0/0 "` Casing valves open to guages, tags hung, DSO notified of well status - Slickline on well at departure END1-67 4/2/2008 "'WELL SHUT IN ON ARRIVAL"*(post rwo) DRIFTED W/ 3.84" NO-GO CENT TO DSSSV AT 1591'MD PULLED 4-1/2" DSSSV FROM 1,591'MD.PULL B& R FROM 11,330' SLM. PULL DCK FROM STA. # 5 AT 3,984' MD. SET 1" DUMMY (BK) IN STA. # 5 AT 3,984' MD. PULLED 4-1/2" RHC PLUG BODY FROM 11,366'MD. LRS MIT-IA TO 3000 # (PASSED) CURRENTLY RIH W/ 3.50" CENT.TEL,S-BAILER. http://digitalwellfile.bp web.bp.com/WIInfo/Reports/ReportViewer.aspx 4/7/2008 Digital ~Vell File "'CONT WSR ON 4~"' • END1-67 4/3/2008 "'CONT WSR FROM 4/2/08"' (post rwo) DRIFTED W/ 3.50" CENT,TEL,S-BAILER (S-BAILER HALF FULL OF WHAT APPEARS TO BE FRAC SAND) LOC TT AT 11,380'SLM+28' CORR.=11,408'MD TAGGED TD AT 11,508'SLM + 28' CORR=11,536'MD SET 4-1/2" MCX (SER#NM-17) AT 1,491'MD. RAN 4-1/2" CHECK SET TO MCX AT 1491'MD (SHEARED) ""'RDMO,LEFT WELL SHUT IN AND TURNED OVER TO OPERATOR"' Print Date: 4/7/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer. aspx Page 2 of 2 4/7/2008 ~ • __ BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: 1-67/T-20 Common Well Name: 1-67/T-20 Spud Date: 11/13/1989 Event Name: WORKOVER Start: 2/29/2008 End: 3/18/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/14/2008 Rig Name: DOYON 16 Rig Number: ' Qate From - To Hours Task Code NPT Phase Description of Operations 2/27/2008 19:00 - 21:30 2.50 MOB P PRE PJSM Prepare to and move off well DS 17-02, Stage to middle of Pad. 21:30 - 00:00 2.50 MOB P PRE N/D BOP stack and install another set of gates and reconfigure stack in preparation for Endicott work, R/D Rig Floor, prepare to lay down derrick. 2/28/2008 00:00 - 03:00 3.00 MOB P PRE Install BOP lifting ring, N/U Double Gates to Mud Cross and install BOPs on Moving Pedistal. 03:00 - 03:30 0.50 MOB P PRE PJSM UD Derrick. 03:30 - 04:00 0.50 MOB P PRE Position rig and install rear Booster Wheels. 04:00 - 17:30 13.50 MOB P PRE Begin to move rig from DS-17 to Endicott with Security escort , and CPS on location to supervise Power Line Crossing coming , off of DS-17. Move Rig Down Endicott Rd to Ice Rd. Take Ice Rd on to SDI and the travel Endicott Causeway to MPI. 17:30 - 20:30 3.00 MOB P PRE Wait on Night BP WSL, Doyon Tour Pusher, Endicott Well Tender, and Area Manager. Conduct "Mini" ATP and Sign Off on Permits. 20:30 - 22:30 2.00 MOB P PRE Remove Rear Boosters, Install BOP's in Cellar on Pedestal. 22:30 - 00:00 1.50 MOB P PRE PJSM. Raise and Pin Derrick. Begin to Rig Up Rig Floor. 2/29/2008 00:00 - 01:30 1.50 MOB P PRE Lay Out Herculite and Plywood around wellhead. 01:30 - 03:00 1.50 MOB P PRE Rig Up Floor and Bridle Down 03:00 - 05:30 2.50 MOB P PRE Move in Modules and from DS 17 and Spot Camp on Ice Pad by SDI. 05:30 - 07:00 1.50 MOB P PRE Lay Down Rig Mats. Place Adapter, Tree, and Shooting Flange Behind Well. 07:00 - 09:00 2.00 MOB P PRE Spot Rig Over Well, have Endicott Well Tender on location. 09:00 - 12:00 3.00 MOB P PRE Spot and R/U #2 Pump Module and 3516 Gen Set Unit. Spot Slop Tank. 12:00 - 12:30 0.50 MOB P PRE Rig Up to Take On Fluids. 12:30 - 14:30 2.00 MOB P PRE ATP Meeting in Endicott Theater. 14:30 - 16:30 2.00 WHSUR P DECOMP Wait on DSM to arrive with Lubricator. Take on 9.8 ppg Brine into pits 16:30 - 17:00 0.50 WHSUR P DECOMP P/U DSM Lubricator. PT Lubricator on Tree to 500 si. Pull BPV. Tb on Vac. IA had -10 si. UD Lubricator and BPV. 17:00 - 20:00 3.00 KILL P DECOMP PJSM. Confirm Line up of Hoses. PT to 4200 psi. Pump 20 bbl Fligh Visc Sweep and Chase with 9.8 ppg Nacl. Took 40 bbls to catch returns. Pumped Total of 750 bbls of 9.8qpa brine at 8 b m with 1 500 si. 20:00 - 20:30 0.50 KILL P DECOMP Monitor well bore. Well is dead. 20:30 - 21:00 0.50 WHSUR P DECOMP Drain Stack in preparation for setting of Two Way Check. 21:00 - 23:30 2.50 WHSUR P DECOMP Set Two Wa Checkand test above to 4,000 si for 10 Charted minutes. Test from below to 2,500 Psi Roling the pumps at 4 BPM to obtain ood 30 minutes test. 23:30 - 00:00 0.50 BOPSU P DECOMP B/D and Rig Down Circulating Lines in Cellar in preparation for N/D Production Tree. 3/1/2008 00:00 - 00:30 0.50 BOPSU P DECOMP B/D R/D Circulating Lines, Vac out Tree. 00:30 - 02:00 1.50 BOPSU P DECOMP N/D Production Tree and Adapter Flange. 02:00 - 02:30 0.50 BOPSU P DECOMP Terminate Control Lines, Check XO in Hanger, Threads Good 10 Turns to fully make up. 02:30 - 06:00 3.50 BOPSU P DECOMP N/U BOPE with 4 Preventers and Bell Nipple. 06:00 - 12:30 6.50 BOPSU P DECOMP Test BOP's. Test Witness Waived bu Bob Noble with Aogcc. Test Rams, Chokes, and Valves to 250 psi low and 4000 psi high. Test Annular to 250 psi low and 3500 psi high. Test with 4", 4-1/2", and 7" Test Joints. Test Wltnessed by BP WSL and Printed: 3/27/2008 1:53:35 PM ~ ~ BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: 1-67/T-20 Common Well Name: 1-67/T-20 Spud Date: 11/13/1989 Event Name: WORKOVER Start: 2/29/2008 End: 3/18/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/14/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/1/2008 06:00 - 12:30 6.50 BOPSU P DECOMP DDI Tool Pusher. 08:30 hrs. Filled annulus with - 7 bbls. 11:00 hrs. Filled annulus with - 4 bbls. 12:30 - 13:30 1.00 BOPSU P DECOMP R/D Test Equipment and Blow Down Choke / Kill Line. B/O 7" Test Joint.. 13:30 - 14:30 1.00 BOPSU P DECOMP P/U DSM Lubricator. Pressure Test to 500 psi. Check Annulus Pressure = Vac. Pull TWC. 0 psi under TWC. UD Lubricator. 14:30 - 17:30 3.00 PULL N HMAN DECOMP Rig Up to Pull Tbg. Bring Top Drive and Work Hydrualics to Warm Up. Found Either Top Drive or Kelly Hose Frozen. PJSM with Rig Crew on thaw operations. Break Loose Kelly Hose from Top Drive. Steam Top Drive - found clear. Kelly Hose Frozen, snake steam hose through end and up kelly hose. Work steam hose for 20-30 mins then use rig air to attempt to clear. Had to work steam hose up - 1/2 way up kelly hose to get through ice plug. Blow air back through to confirm clear. Clrculated through tbg and up annulus while thawing at - 2 bpm and 40 psi with charge pump. Loosing - 1 17:30 - 18:00 0.50 PULL N HMAN DECOMP Install Kelly hose back on top drive. Pressure Test to 3000 psi. 18:00 - 19:30 1.50 PULL P DECOMP M/U Top Drive and BOLDS, pull hanger to righ floor, hanger and tubing pulled free at 150,000#, string weight 155,000# 19:30 - 20:30 1.00 PULL P DECOMP CBU at 10 bpm with 700 psi. A lot of Frac sand noticed at shakers on bottoms up. 20:30 - 21:00 0.50 PUL~ P DECOMP Terminate Control Lines, UD Hanger, B/D Top drive. 21:00 - 22:00 1.00 PULL P DECOMP L/D 4.5" tubin to SSSV for a total of 38 jts, recovered all of the control line and 4 Stainless Steel Bands and 19 Rubber Clamps. 22:00 - 22:30 0.50 PULL P DECOMP R/D SLB Control line spooler, SLB normed the control line before leaving location. 22:30 - 00:00 1.50 PULL P DECOMP Continued to lay down 4.5" completion. 3/2/2008 00:00 - 06:00 6.00 PULL P DECOMP Continue to pull 4.5" Completion, Tubinq in qood Condition No erosion on pin or box ends, tubes in good condition also. UD a total of 264 Full Jts, SSSV Assembly, 6 GLM Assemblies, Cut Jt on bottom pup of last GLM ( 3.62'). Cut had very little bell and flare to it max OD= 4.87". 06:00 - 06:30 0.50 PULL P DECOMP Rig Down Tbg Handling Equipment. Clear and Clean Rig Floor. Swap Out XO on Floor Valve. 06:30 - 07:00 0.50 PULL P DECOMP Drain Stack. Two Clamps in Stack. R/U to Annulus and Flush Clamps Up and Out of Stack. Recover Clamps in Drip Pan. 07:00 - 07:30 0.50 CLEAN P DECOMP Drain Stack and Install Wear Ring. 07:30 - 08:30 1.00 CLEAN P DECOMP P/U 9 Joints of 6-1/4" Drill Collars from Pipe Shed. RIH, then POOH and Rack Back in Derrick while waiting on Wash Pipe Shoe and E~ension to arrive. 08:30 - 09:30 1.00 CLEAN P DECOMP Load Wash Pipe in Shed. Strap and Tally. Bring Subs to Floor and Steam. 09:30 - 12:00 2.50 CLEAN P DECOMP P/U and M/U Wash Over BHA. 8-3/8"x7-1/2" Toothed Shoe, (2) 8-3/8" Wash Pipe Extensions, 8-1/8"x8-3/8" Bushing, Jt of 8-1/8 Wash Pipe, Wash Pipe Drive Sub, Bumper Sub, Oil Jar, , 4-1/2" Reg x 4-1/2" IF XO, 4-1/2" IF x 4-1/2" Reg Bit Sub with Ported Float, H90x4-1/2" IF XO, (9) 6-1/4" DC's. Total Length = 383.92' Printed: 3/27/2008 1:53:35 F'M ~ ~ ~ BP E Operation; Legal Well Name: 1-67/T-20 Common Well Name: 1-67/T-20 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 3/2/2008 12:00 - 23:30 11.50 CLEAN P 23:30 - 00:00 0.50 CLEAN P 3/3/2008 00:00 - 00:30 0.50 CLEAN P 00:30 - 01:00 0.50 CLEAN P 01:00 - 02:30 I 1.501 CLEAN I P 02:30 - 03:30 I 1.001 CLEAN I P 03:30 - 04:00 0.50 CLEAN P 04:00 - 07:00 3.00 CLEAN P 07:00 - 08:30 1.50 CLEAN P 08:30 - 09:00 I 0.50I CLEAN ~ P 09:00 - 10:00 1.00 CLEAN P 10:00 - 13:30 3.50 CLEAN P 13:30 - 14:00 0.50 CLEAN P 14:00 - 15:00 I 1.001 CLEAN I P 15:00 - 16:30 ~ 1.50 ~ CLEAN ~ P 16:30 - 20:00 I 3.50 I CLEAN I P 20:00 - 21:30 I 1.50 I CLEAN I P 21:30 - 22:00 I 0.501 CLEAN I P 22:00 - 23:30 1.50 CLEAN P 23:30 - 00:00 0.50 CLEAN P 3/4/2008 00:00 - 03:30 3.50 CLEAN P P'LORATION Page 3 of 12 Summary Report Spud Date: 11 /13/1989 Start: 2/29/2008 End: 3/18/2008 Rig Release: 3/14/2008 Rig Number: Phase Description of Operations DECOMP RIH with Wash Over BHA. P/U DP from Shed and RIH ix1, Filling on Fly and Breaking Circulation every 60 Joints. DECOMP Slip and Cut drilling line, cut 19 wraps for a total of 128'. DECOMP Continue to Slip and Cut Drilling Line. DECOMP Continue to RIH to 10,575, obtain parameters up weight= 207,000#, down weight=165,000#, rotating weight=175,000# at 30 rpm, 6,000 ft-Ibs of torque, pumps at 8 bpm with 2,130 psi. DECOMP RIH and Ta ed at 10 609' ossibl on sand washed down t 30 rpm and 8 bpm with 2,130 psi, continued to wash down and ta ed u on XO above the SBR at 10 629' continued to work down to to of acker at 10 642' with 10,000# down weight. Top of fish at 10,618', On intital B/U significant amount of Sand and a smoo lookin substance seen comin over the shakers. DECOMP Pump 20 bbl Hi-Vis sweep at 11 bpm and 2,830 psi. As the sweep returned to surface more sand was ahead of the sweep and cleaned up before sweep was fully pumped out of the hole. DECOMP Monitor well and pumped 15 bbl dry job, B/D T/D DECOMP POOH from 10 642' Stand Back DP. DECOMP UD Accelerators, Stand Back 6-1/4" DC's, B/O & UD Wash Pipe. DECOMP Clean and Clear the Rig FLoor. Gather Up O/S Grapple Subs and Pieces. DECOMP M/U OS Grapple BHA. DECOMP RIH W/ ~S rrannle ~HA on DP From Derrick. DECOMP RIH to 10587'. Take Initial Parameters. P/U Wt = 210,000 Ibs S/O Wt = 160,000 Ibs Rot Wt = 185,000 Ibs Free Torque = 6000 ft-Ibs with 20 RPM's. Pump Rate 6 bpm at 830 psi. S/O down to top of tbg stub. Tag at 10619'. P/U and Start Rotation at 50 RPM's and 6,000 ft-Ibs. S/O and Rotate over Tubing Stub. Once over a ft quit rotation. Continue to Slack Off a full 6 ft, shut down pumps as pressured up sliding over. DECOMP P/U to 50,000 over and let jar go off. Slack off to 15,000 over rotating Wt and Attempt ot Rotate Out Anchor Assembly. Able to get 16 rotations and Up to 13,500 ft Ibs of torque before grapples slipped. Make 2nd attempts with same results. Make 2 jar licks at 65,000 Ibs over. S/O again and Make 3rd attempt to rotate out anchor assembly. No-Go. Grapples slipped after 16 rotations and -13,500 ft-Ibs torque. Re-cocked the jars and make 2 Jar licks at 85,000 Ibs over. Movin U hole. Dra in -10 000 Ibs over. DECOMP Pump 20 bbls High Visc Sweep and Pump around at 12 bpm and 2800 psi. A noticeable amount of sand seen at shakers ~vith bottoms up and just before sweep came back. DECOMP B/O and Blow Down Top Drive, Monitor Hole. POOH and Stand Back DP. DECOMP UD Intensifier, stand back drill collars, UD SBR and Pup Jts =27.95'. DECOMP B/O Overshot and re-dress with 5 3/8" Grapple, clean junk basket very little sand in JB. DECOMP M/U BHA#3 DECOMP RIH with drill pipe from 337' to 1,284'. DECOMP Continue to RIH from 1,284' to 10,590', obtain parameters: up weight=212,000#., down weight=162,000#, rotating Printed: 3/27/2008 1:53:35 PM , ~ • BP EXPL Qperations S~ Legal Well Name: 1-67/T-20 Common Well Name: 1-67/T-20 , , ,..,, . Page 4 c ~~4~~~ary r~~Nur i Spud Date: 11 /13/1989 Event Name: WORKOVER Start: 2/29/2008 End: 3/18/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/14/2008 Rig Name: DOYON 16 Rig Number: Date From - To ' Hours Task Code NPT Phase ' Description of Operations 3/4/2008 00:00 - 03:30 3.50 CLEAN P DECOMP weight=182,000# with 20 rpm and 5,000 ft-Ibs of torque, 6 bpm 03:30 - 04:30 I 1.001 CLEAN I P 04:30 - 05:30 I 1.001 CLEAN I P 05:30 - 06:00 0.50 CLEAN P 06:00 - 09:30 3.50 CLEAN P 09:30 - 10:30 1.00 CLEAN P 10:30 - 11:00 0.50 CLEAN P 11:00 - 12:00 1.00 CLEAN P 12:00 - 15:30 3.50 CLEAN P 15:30 - 17:00 1.50 CLEAN P 17:00 - 17:30 I 0.501 CLEAN I P 17:30 - 23:30 I 6.001 CLEAN I P 23:30 - 00:00 I 0.501 CLEAN I P 13/5/2008 100:00 - 03:30 I 3.501 CLEAN I P 03:30 - 08:30 3.50 CLEAN P 08:30 - 10:30 2.00 CLEAN P with 760 psi. DECOMP Continue to wash down at 6 bpm and 760 psi, tagged at 10 6, 29' pressure increase to 990 psi as swallowed slick stick, continued to slack off another 9', tagged No-Go presure increase to 1,600 psi, reduced rate to 2 bpm and 80 psi, pulled up on drillstring to 250,000# let jar fire 4 times to loosen K-Anchor, slack off to 200,000# up weight and began right hand rotation 19 turns lost torque, pulled up on drillstring and had an overpull, slacked off to 200,000# and began 15 turns to the right torque fell off, picked up on drillstring and still had an overpull, slacked off to 200,000# and began right hand rotation, 15 turns to the right, pick up on drillstrinq and fish pulled free. To Confirm we had the K-Anchor we slacked off and relatch K-Anchor picked up on drillstring and had an overpulf , K-Anchor latched. Rotated drillstring to the right 15 turns and pulled fish free picked up 30' with ~ 5,000# increase on the weight indicator. DECOMP CBU at 10 bpm with 2,230 psi.,Nothinq of note on B/U over shakers. DECOMP Monitor wellbore, pump 15 bbl dry job, blow down top drive. DECOMP POH and S/B DP in Derrick. UD jars, S/B DCs. DECOMP B/O and UD Overshot seal assembl and K-anchor. Clean junk baskets and get 1-gallon of cement debris. DECOMP Clear and clean rig floor. DECOMP M/U BHA #4:Packer Retrievinq Tool Assemblv, Triple Connnection Bushing, 8-1/2" OD Packer Mil, 3-ea Boot Baskets, Bumper sub, Oil Jar, Pump-out sub, 9-ea DCs, and Intensifier. DECOMP RIH BHA #4 on DP from Derrick. DECOMP Slip and cut 128' of drilling line. Driller held a very good PJSM to cover every aspect of the job. DECOMP P/U single joint of drill pipe and establish parameters: P/U wt 224K-Ibs, 6-BPM, 1160-psi, S/O wt 160K-Ibs. Wash down from 10,597' to 10,628' without seeing any bobbles on weight indicator. P/U second single and wash down to taq up at 10 641'. Slip into packer and P/U 250K-Ibs to ensure grapples have engaged. S/O to establish milling parameters: 5.7-BPM, 1110-psi, free torque 5-6K-Ib-ft. Set 4-5K-Ibs WOB and start milling operations. DECOMP k ' I' erations with the following parameters: 80 rpm, 4 to 20 wob, pump rate, pump rate of 5.5 bpm with 1,100 psi, pumping 20 bbl Hi-Vis Sweeps as needed. Very little debris came back with sweeps. DECOMP Packer broke free and ushed acker down 6' and then PUH 30' to verif acker on PRT. Noticed a little drag, came back down. B/O Top Drive Blow down same, P/U single of 4" drill pipe and pushed packer 3' down to the 7" liner top. DECOMP Establish loss rate of 12-BPH, then circulate two wellbore volumes with Hi-Vis sweeps, 8-BPM at 2,980-psi. Monitor well and verify loss rate at 12-BPH. DECOMP POH and S/B DP in Derrick. B/O and UD DCs. DECOMP Had to BOLDS to allow Wear Ring to be pulled to rig floor with Printetl: 3/27/2008 1:53:35 PM ~ • BP EXPLORATION Page 5 of 12' Operations Summary Report Legal Well Name: 1-67/T-20 Common Well Name: 1-67/T-20 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date' From - To Hours Task Code NPT 3/5/2008 08:30 - 10:30 2.00 CLEAN P 10:30 - 11:00 0.50 CLEAN P 1 f:00 - i2:30 1.50 CLEAN P 12:30 - 14:30 2.00 CLEAN P 14:30 - 18:00 3.50 CLEAN P 18:00 - 00:00 6.00 CLEAN P 3/6/2008 00:00 - 01:00 1.00 CLEAN P 01:00 - 02:00 1.00 CLEAN P 02:00 - 03:30 1.50 CLEAN P 03:30 - 05:00 1.50 CLEAN P 05:00 - 08:00 3.00 CLEAN P 08:00 - 10:30 2.50 CLEAN P 10:30 - 11:00 0.50 CLEAN P Spud Date: 11 /13/1989 Start: 2/29/2008 End: 3/18/2008 Rig Release: 3/14/2008 Rig Number: Phase Description of Operations DECOMP Packer. Packer had pieces of packer and slips adhered with schmoo to packer. PJSM for using tubing punch and Backing Out and Laying Down Tubing under packer. Punched tubing at mill out extension and drained fluid, punched second hole and drained Schmoo,punched the third hole and released a significant amount of gas, lel of 10% and H2s at 5ppm in Pits. Punched the 4th hole and found no pressure under fas-drill plug. Continued poking holes with no releases. DECOMP P/U Packer and B/O and Lay down packer and BHA componets, DECOMP Clean out junk baskets 30 Ibs of inetal recovered. While cleaning out the junk baskets we lined up to circufate under the blinds thru choke manifold the combo alarm sounded in the pits, Stopped operations and lined up to the Gas Buster and circulated out gas. Cleared and Cleaned the Rig Floor. P/U BHA Components. DECOMP M/U BHA #5, BHA consists of: Shoe with finger basket, xo bushing, extension, extension, reverse circulating junk basket, bumper sub, xo, 9-4 3/4" drill collars. DECOMP Continue to RIH from 321' to 3,168' pumping a pipe volume every 10 stands to circ out gas, pumping weighted pills as needed to keep pipe from u-tubing, siqnificant amout of crude . back to surface. DECOMP Amount of gas and crude reduced, ran 20-stands of drillpipe in to a depth of 5,162' and Pumped 1 annular volume to stage in and circulate out gas. RIH to 7,060' and circulated 1 annular volume again and allowed gas to break out. DECOMP Continue to circulate annulus volume at 7,060' at 8 bpm and 720 psi, Siqnificant amount of qas and crude back to s~~rfar.P pump 10 bbl dry job. DECOMP RIH from 7,060'to 10,684'. DECOMP CBU at 8 bpm and 1,200 psi, still seeinq a lot of qas and crude coming back on bottoms u. Pumped 10 bbl dry job. B/D T/D. DECOMP POOH and rack back 5 stands, to 10,194'. P/U Drill Pipe from pipe shed 1x1 to 11,112'.Taqged Liner Top at 10,659'. DECOMP Obtain parameters: up weight=208,000-Ibs, down weight=160,000-Ibs, rotating weight=160,000-Ibs, at 50-RPM, 5,000-Ib-ft of free torque. Wash down from 11,112' to 11,142' at 7-BPM with 1,300 psi, B/O T/D and drop reverse circulating ball down drill pipe, allow ball to fall on seat and continue to wash down at 7-BPM with 1,600-psi, rotating at 50-RPM. P/U stand #118 and slowly RIH; lightly taq somethinq at 11,492', mark pipe and P/U. RBIH slowly and do not see anything until a liqht tag at 11,502', mark pipe, P/U and RBIH slowly for a light tag at 11,504'. Repeat the pipe marking, P/U, and slow RBIH process 5-more times and make it to 11,519'. Decide to P/U, drop pump-out sub opening ball/rod and circulate bottoms up. DECOMP Circulate bottoms up at 8-BPM at 1100-psi. Get Scmoo back across shakers and the smell of gas. Discuss Schmoo removal with ADW. Circulate 2 surface-to-surface volumes, -1,500-Bbls. DECOMP S/D and monitor well. An occasional small gas bubble at the surface for the first few minutes while the fluid level continued Printed: 3/27/2008 1:53:35 PM ~ • _ BP EXPLORATION Page 6 of 12 Operationns Summary Report Legal Well Name: 1-67/T-20 Common Well Name: 1-67/T-20 Spud Date: 11/13/1989 Event Name: WORKOVER Start: 2/29/2008 End: 3/18/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/14/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/6/2008 10:30 - 11:00 0.50 CLEAN P DECOMP to drop slowly, then no gas bubbles observed. Start hole fill pump and calculate loss rate of 7-BPH. Discuss with ADW and decide to POH, but watching for gas breakout and Schmoo on DP when POH. 11:00 - 16:30 5.50 CLEAN P DECOMP POH and S/B DP and DCs in Derrick. There was no evidence of "Schmoo" on any of the Drill Pipe while POH. Average fluid loss was 7-BPH while POH. The entire WRP with running tool was pulled to the surface inside the JRCB. No as released from the fluid while POH. 16:30 - 18:30 2.00 CLEAN P DECOMP Break out and UD the fish, Shoe with fingers, washpipe extensions, JRCB, jars, Bumper sub, and pump out sub. 1-gallon of debris recovered from the bottom of the washpipe. A 2-foot long piece of 5/8" diameter solid steel rod was wrapped around the bullnose end of the WRP. It looks like a string-shot mandrel. 18:30 - 19:30 I 1.001 CLEAN I P 19:30 - 22:00 2.50 CLEAN P 22:00 - 22:30 0.50 CLEAN P 22:30 - 23:00 I 0.50 I CLEAN I P 3/7/2008 00:00 - 01:00 1.00 CLEAN P 01:00 - 01:30 0.50 CLEAN P 01:30 - 05:00 3.50 CLEAN P 05:00 - 05:30 0.50 CLEAN P 05:30 - 06:30 1.00 CLEAN P 06:30 - 11:30 ~ 5.00 ~ DHB ~ P DECOMP M/U Clean out assembly BHA consists of: Bit, 7" Casing Scraper, 2-Junk Baskets, Bit Sub, Bumper Sub, Oil Jar, Pumpout Sub, XO, 9-4 3/4" Drill Collars. BHA Length=313.96' DECOMP Continue to RIH from 313' to 10,759'. DECOMP Made Multiple Passes through Packer setting area from `10759' to 10.809'. DECOMP M/U to T/D at 11,418' and obtain parameters: up weight= 200,000#, down weight= 170,000#, 60 rpms, 5,000# free torque , Continue to washing down at 8 bpm with 1,135 psi. P/U 1-stand at a time and washing down. Tagged up at 11,523', but drilled off fast. Continue to clean down and tag up hard at a final de th of 11 534'. DECOMP Pump 20-Bbl Hi-Vis Sweep at 10-BPM with 2430-psi. DECOMP Monitor Well, Pump 15-Bbl dryjob and B/D T/D. DECOMP POOH from 11,523'to BHA. DECOMP Stand back 4-3/4" drill Collars. DECOMP Break down BHA components B/O Bit. Found very little debris in the Junk Baskets with a small amount of Schmoo. Clear and clean Rig Floor. DECOMP P/U Halliburton RBP and RIH to set inside the 7" Liner with the ~r.Pnter of the elements at 10.761' and the toD of the stem at 11:30 - 12:30 1.00 CLEAN P DECOMP R/U chart recorder and lines to pressure test RBP to 2,500-psi. Bring rig pump on and increase pressure on DP to 2,500-psi. Leak off is 5-1/2-BPM to keep 2,500-psi on the DP. Shut in the pump and the pressure immediately dropped to 1,000-psi, then gradually decreased to 350-psi in 15-minutes. Informed ADW engineer and continued on with RWO. 12:30 - 13:00 0.50 CLEAN P DECOMP Circulate one DP volume, 116-Bbls, prepare to dump 20-40 river sand. 13:00 - 14:30 1.50 DHB P DECOMP Modify sand hopper. Dum~ 20-baqs of 20-40 river sand. Prepare to slip and cut Drilling Line. 14:30 - 15:30 1.00 CLEAN P DECOMP Slip and cut 128' of Drilling Line. 15:30 - 16:30 1.00 CLEAN P DECOMP Circulate a Drill Pipe volume, 116-Bbis to ensure all sand is out of the string. Taq top of the sand at 10,694' for 62' of cover over the RBP stem. 16:30 - 20:00 3.50 CLEAN P DECOMP POH and S/B DP in Derrick. 18-stands POH at 1700-hours. 20:00 - 20:30 0.50 CLEAN P DECOMP UD RBP running tool and gather next BHA. Printetl: 3/27/2008 1:53:35 PM ~ • BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: 1-67/T-20 Common Well Name: 1-67/T-20 Spud Date: 11/13/1989 Event Name: WORKOVER Start: 2/29/2008 End: 3/18/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/14/2008 Rig Name: DOYON 16 Rig Number: ' Date From - To Hours Task Code NPT Phase Description af Operations 3/7/2008 20:30 - 21:30 1.00 CLEAN P DECOMP M/U Polish Mill Assembl BHA consists of: Polish mill, xo, junk basket, 9 5/8" casing scraper, junk basket, bit sub, bumper sub, oil jar, pump out sub, xo, 9-4 3/4" drill collars. BHA length=322.46' 21:30 - 00:00 2.50 CLEAN P DECOMP Continue to RIH with Polish Mill Assembly from 322' to 8,864', Worked scra er through the 9 5/8 ZXP Liner Hanger setting area between 2,675' and 2,790 . 3/8/2008 00:00 - 01:30 1.50 CLEAN P DECOMP RIH from 8,864' to 10,575', Obtain Parameters: up weight=185,000#, down weight=162,000#, rotating weight=175,000#, at 40 rpm with 5,000 Ibs-ft free torque. 01:30 - 02:00 0.50 CLEAN P DECOMP Tagged liner top at 10,659' clean out though liner seal bore, to 10,664' Rici rocated area, circulated at 11 bpm. 02:00 - 03:30 1.50 GLEAN P DECOMP Circulated Hi-vis sweep at 12.5 bpm and 3,280 psi. 03:30 - 08:30 5.00 CLEAN P DECOMP POOH from 10,664'. 08:30 - 09:30 1.00 BOPSU DECOMP R/U to perfrom weekly BOPE test. 09:30 - 19:00 9.50 BOPSU P DECOMP Test BOPE 250-psi low, 3,500-psi high for the Hydril and 250-psi low, 4,000-psi high for the remainder, using 4", 4-1/2", and 7" test joints. AOGCC's John Crisp waived at 0600-hours, State's right to witness the BOPE test. Pull Test plug, check it and re-install it correctly inside Casing Spool. 19:00 - 19:30 0.50 BOPSU P DECOMP B/D Choke and kill lines, pull test plug, set wear ring, break down test joints. 19:30 - 21:00 1.50 EVAL P DECOMP N/D flow riser, N/U Shooting Flange, Load SLB tools to the pipe shed and bring them to the rig floor. 21:00 - 21:30 0.50 EVAL P DECOMP Continue to gather SLB tool and thaw them out. 21:30 - 00:00 2.50 EVAL P DECOMP PJSM with Schlumberger on rigging up full pressure control equipment. Make up 30' of riser in Pipeshed. 3/9/2008 00:00 - 02:00 2.00 EVAL P DECOMP PJSM with SLB E-liners on rigging up full pressure control equipment. 02:00 - 03:30 1.50 EVAL P DECOMP R/U Wire Line tools and Pressure Test SWS Riser and Well Control Equipment to 500 psi. Plus 1 hour Day liglht Savings Time Adjustment. 03:30 - 05:00 1.50 EVAL P DECOMP Calibrate tool and RIH to 3,000'. 05:00 - 06:00 1.00 EVAL P DECOMP Log up from 3,000' at 4,000' per/hr. 06:00 - 07:30 1.50 EVAL P DECOMP RIH to 2,400' and re-run in High-Resolution mode up to 2,200'. Find 9-5/8" TOC at 2,335' and two corrosion pitting areas at 2,415' and 2,360'. POH with USIT logging tool. 07:30 - 10:00 2.50 EVAL P DECOMP Rig down Schlumberger equipment. During R/D a near-miss occurred when the Schlumberger pressure control string dropped 6" while it was being lowered back down onto the 7" Otis connection of the shooting flange on top of the Doyon 16 BOP stack. See more information in "Remarks". 10:00 - 11:00 1.00 BOPSU P TIEB2 N/D Shooting Flange and N/U Drilling Riser. 11:00 - 13:00 2.00 BOPSU P TIEB2 R/U to run 7", 26# Scab Liner. P/U Doyon casing running equipment and bring onto Rig Floor. 13:00 - 14:00 1.00 CASE P TIE62 Service TopDrive and Draworks. 14:00 - 15:00 1.00 CASE N TIE62 Changeout Pipe Skate Koomey bladder and service skate. 15:00 - 23:00 8.00 CASE P TIEB2 PJSM. P/U Baker 7" Seal Stem assembly with float Collar and M/U (Bakerloked) to full joint of 7", 26# casing. Then P/U and M/U (BakerLoked) full joint of casing with Landing Collar inserted near pin end. Continue RIH with 7", 26# casing using Best-O-Life pipe dope and torquing all connections up to the stamp at the pin end, 8,000 ft-Ibs of torque. Printetl: 3/272VOtl i:5s:~o rnn ~ . ~ ~ • BP EXPLORATION Page 8 of 12 Operrations Summary Report Legal Well Name: 1-67/T-20 Common Well Name: 1-67/T-20 Spud Date: 11/13/1989 Event Name: WORKOVER Start: 2/29/2008 End: 3/18/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/14/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/9/2008 23:00 - 00:00 1.00 CASE P TIEB2 C/O Elevators and P/U ZXP Liner top Packer, M/U ZXP to 7" Casing. 3/10/2008 00:00 - 01:30 1.50 CASE P TIE62 Circulate Liner Volume of 303 bbls at 7.5 bpm with 950 psi, Liner up weight=220,000#, down weight=204,000#. 01:30 - 03:00 1.50 CASE P TIEB2 RIH with 7" liner on 4" drill pipe,at 100 fpm. 03:00 - 03:30 0.50 CASE P TIE62 Obtain parameters: up weight=255,000#, down weight=215,000#. 03:30 - 04:00 0.50 CASE P TIEB2 Work TIW Seal Assembly into PBR at 10,619', Had to orient 04:00 - 05:00 1.00 CASE P TIE62 Space out to allow the cement head to be at the rig floor, rack back one stand, pick up on jt of 4" and a 15' pup jt. R/U cement head to drill string , R/U cement hoses and valves and pump 50 bbis of 9.8 brine to break circulation. 05:00 - 05:30 0.50 CASE P TIEB2 PJSM with CH2M Hill Truck Drivers, Mud Engineer, SLB Cementer, Rig Crews, Toolpusher and Co Man to discuss safety aspect of and the operations involved in the cement job. 05:30 - 06:00 0.50 CASE P TIEB2 Pressure up on Drill String to 500 psi and began to pick up on string until pressure bled off, indicating that the cementing ports were clear of PBR and in position to cement. Dowell pump 5-Bbis freshwater for PT'ing lines to 4,500-psi. 06:00 - 06:45 0.75 CEMT P TIEB2 Dowell batch mix 235-Bbis Class G"NeaY' 15.8-ppg cement; includes -15-Bbls excess. StaR pumping cement slurry 5.5-BPM at -800-psi. Catch sample for UCA lab testing. Stop Dowell pumping with 230.4-Bbls cement slurry away. Taking all returns to Pits. 06:45 - 08:30 1.75 CEMT P TIEB2 S/D Dowell pump, drop dart, chase dart into DP with Dowell pump with 5-Bbls freshwater. Switch over to Rig Pump to displace cement into annulus. Taking all returns to Pits. Pump at 5.1-BPM, pumping 9.8-ppg brine from Pits, keeping pump pressure below 1000-psi. Slow pump to 4-BPM, 1200-psi with -230-Bbis displacement pumped. At 285-Bbls pumped, slow pump to 3-BPM at 1350-psi. At -295-Bbls displaced, slow pump to 2-BPM, 1450-psi. At 308-Bbls dislaced, slow pump to .75-Bbls, 2000-psi. Bump plug with 322-Bbls displaced. _ 08:30 - 08:45 0.25 CASE P TIE62 Slack off 50,000-Ibs from DP weight to 165,000-Ibs. Increase pressure to 3,200-psi to set the Liner Hanger. Slack off the remainder of the Liner weight plus 20,000-Ibs, placing 115,000-Ibs of down weight on the Liner Hanger. Pressure up to 4,300-psi to set the Baker ZXP Liner Top Packer. Bleed off pressure to check the floats. Floats holding. Rotate DP 10-turns to release running tool from Liner. 08:45 - 10:30 1.75 CASE P TIE62 Line up to take returns to Slop Tank. P/U on DP and reverse out excess cement. Pump Contaminate pill into Slop Tank. Reverse circulate 8-BPM at 800-psi; pump 70-Bbls and returns are clean of cement. Estimate 7-10-Bbls of excess cement in Slo Tank. 10:30 - 11:00 0.50 CASE P TIEB2 B/O and L/D cementing head, DP pup joint and one DP single. Realign valves and circulate long way at 12-BPM, 2000-psi while reciprocating pipe 60'. Returns have no cement but include a very small amount of schmoo. 11:00 - 12:30 1.50 CASE P TIE62 POH with Tieback running tool. S/B DP in Derrick. B/O and UD tieback running tool. 12:30 - 15:00 2.50 WHSUR P TIEB2 BOLDS. Pull Wear Ring with FMC supervision. M/U 9-5/8" Printetl: 3/27/2008 1:53:"Sb F'nn . . • • BP EXPLORATION' Page 9 of 12 ~perations Summary Report Legal Well Name: 1-67/T-20 Common Well Name: 1-67/T-20 Spud Date: 11/13/1989 Event Name: WORKOVER Start: 2/29/2008 End: 3/18/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/14/2008 Rig Name: DOYON 16 Rig Number: ' Date From - To Hours Task Code NPT Phase Description of Operations 3/10/2008 12:30 - 15:00 2.50 WHSUR P TIE62 packoff pulling tool to landing joint, RIH, engage 9-5/8" packoffs. P/U to 60,000-Ibs and packoffs come free. They were packed with plastic material. Install new 9-5/8" packoffs and test packoffs to 3,800-psi, per FMC, for 30-minutes, charted. 15:00 - 15:30 0.50 WHSUR P TIEB2 Se19" Wear Ring. RILDS. 15:30 - 17:30 2.00 CASE P TIE62 M/U BHA #8: 6" Mill Tooth Bit, 2-ea Boot Baskets, Bumper Sub, Oil Jars, 2-ea 4-3/4" DCs, 6-1/8" String Mill (at 97' above the Bit), and 6-ea 4-3/4" DCs. 17:30 - 21:00 3.50 CASE P TIE62 RIH BHA #8 on DP from Derrick. From 322' to 10,480'. 21:00 - 22:00 1.00 CASE P TIE62 Slip and Cut Drilling Line, cut 128' of drilling line. Circulating at 3 bpm while servicing rig. 22:00 - 23:30 1.50 CASE P TIE62 B/O of top drive and contunue to RIH to M/U to T/D at 10,480'. Obtain parameters and wash down to 10,544' at 4 bpm with 500 psi, up weight=200,00#, down weight=155,000#, rotating weight=174,000#, 70 rpm, 7,000 ft-Ibs torque. Tag up on cement at 10,544' drill cement to 10,590'. 23:30 - 00:00 0.50 CASE P TIEB2 CBU at 11 bpm with 3,140 psi. 3/11/2008 00:00 - 01:00 1.00 DRILL P TIEB2 Pick up to 10,544' R/U to Test casinq to 3,500 psi and Chart for 10 minutes, good test 01:00 - 04:30 3.50 DRILL P TIEB2 Obtain Parameters: up weight=205,000#, down weight=155,000#, rotating weight 175,000# at 80 rpm, 8,000 ft-Ibs torque, Tagged landing collar at 10,590', Control Drill with 5 to 10,000# wob, with 4 bpm and 590 psi. Drilled with 80 to 100 rpm, and 8-10,000 ft-Ibs torque, drilled 5' through float equipment. 04:30 - 06:00 1.50 DRILL P TIE62 Drill Cement from 10,595' to 10,664' at 90 rpm with 8-11,000 ft-Ibs of torque, 5,000 wob, 11 bpm, 3250 psi. 06:00 - 07:30 1.50 DRILL P TIE62 Pump 20-Bbl Biozan sweep at 11-BPM, 3,200-psi and get lots of cement, rubber chunks, and fine aluminum shavings across the shakers during circulation. 07:30 - 08:30 1.00 DRILL P TIEB2 S/D pumps. RIH and attempt to dry tag sand cap at 10,694', slack off 10' but don't see an indication. P/U and discuss with ADW engineer. 08:30 - 10:00 1.50 DRILL P TIEB2 Get parameters: P/U 205K-Ibs, S/O 157K-Ibs, 1-BPM, 40-psi, 40-RPM, 7-K-Ib-ft free torque and washdown, seeing no indication of a sand cap other than slight bobbles on the weight indicator. Washdown to 10,734', leaving -22' of sand cover on to of the RBP. P/U, stop rotating, but reciprocate a few strokes and circulate a Hi-Vis sweep all the way around at 11-BPM and 3,200-psi. Brinq lots of sand back across the Shakers when swee comes to surface. Pump dry job to start POH. I 10:00 - 13:30 3.50 CASE P TIEB2 POH and S/B Drill Pipe and Drill Collars in Derrick. 36-stands out at 1130-hours. Crew change PJSM. 55-stds out ~ 1215-hrs. 95-stds @ 1310-hrs. 13:30 - 14:30 1.00 CASE P TIE62 S/B 2-stands of Drill Collars. B/O and UD String Mill. S/B 1-stand of Drill Collars. Empty Junk Baskets and get -1-1/2-gallons of cuttings with some chunks of cement, brass, and rubber. 14:30 - 15:00 0.50 CASE P TIEB2 P/U and M/U Halliburton 7" RBP Retrieving Tool and overshot. 15:00 - 18:00 3.00 CASE P TIEB2 RIH with RBP etrieving oo an overs o on ri ipe and Drill Collars from Derrick. Stop above HES RBP and prepare to swap out fluid. Printed: 3/27/2008 1:53:35 PM ~ ~ --- BP EXPLORATION Page 10 of 12 4perations Summary Report Legal Well Name: 1-67/T-20 Common Well Name: 1-67/T-20 Spud Date: 11/13/1989 Event Name: WORKOVER Start: 2/29/2008 End: 3/18/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/14/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase ' Description of Operations 3/11/2008 18:00 - 19:30 1.50 CASE P TIEB2 Establish parameters of Up Wt-200,000 Ibs; Down Wt- 150,000 Ibs. Establish circulation at 9 bpm with 3200 psi. PJSM with rig crew and CH2MHill vac truck drivers. Discuss up coming displacement, spill and prevention, fluid transfers and procedures, pit designation for new brine and dirty returns. RIH and tag sand at 10,741'. Wash through sand on top of HES RBP to 10,756'. Clean and load pit 4 with new 9.8 ppg NaCI Brine. 19:30 - 20:30 1.00 CASE P TIEB2 Pump 20-Bbl high visc sweep and chase with new 9.8 ppg NaCI Brine at 6-9 bpm with 960-2070 psi to displace well. Hiqh visc sweep brought back an increase in dirt returns. Continue cleaning pits while displacing. 20:30 - 21:00 0.50 CASE P TIEB2 Continue to clean pit 2 before taking clean returns into pits. Fill pit for circulating well after releasing RBP. 21:00 - 21:30 0.50 CASE P TIEB2 RIH to top of HES RBP at 10,756'. Tag and sting retrieving tool to HES RBP. Turn 1/2 turn to right and pick up overpull to 205,000 Ibs. Set back down to 130,000 Ibs. Turn 1/4 right hand turn and pick up to 215,000 Ibs. Worked torque to RBP. ,Set back down past set depth. Pick up and let PKR elements relax. 21:30 - 22:30 1.00 CASE P TIEB2 CBU at 6 bpm with 970 psi. Bottoms up had small amounts of gas and crude and cleaned up immediately after bottoms up. Dynamic losses at 18 bph. Monitor well static losses at 15 b h. 22:30 - 00:00 1.50 CASE P TIEB2 Pump Slug and POOH with HES RBP standing back 4" HT-38 Drill Pipe in Derrick with 15-20k drag off bottom. 3/12/2008 00:00 - 04:00 4.00 CASE P TIEB2 Continue POOH with HES RBP standing back 4" HT-38 Drill Pipe in Derrick. UD HES RBP and retrievina tool. 04:00 - 05:00 1.00 CASE P TIEB2 P/U HES Cham PKR on 3 stands of Drill Collars from Derrick. 05:00 - 09:00 4.00 CASE P TIE62 RIH with HES Champ PKR on 4" HT-38 Drill Pipe from Derrick. 25-stands at 0600-hours. 09:00 - 11:00 2.00 CASE P TIEB2 Get parameters: P/U wt 205K-Ibs, S/O wt 160K-Ibs. Set Champ Packer at 11 386'. Pressure up twice and inject 3-BPM at 750-psi. Call ADW engineer and decide to chase leak uphole. 11:00 - 15:00 4.00 CASE N HMAN TIEB2 Test at 11,386', 11,291', 11,010', 10,818', 10,725', 10,631', 10,537'. Called Halliburton during these tests and realized that the Halliburton tech thought that his tool was being tested from ' the backside, which was the correct method, but the Driller thought that he was supposed to test the casing by pumping ', down the Drillpipe. WSL witnessed all tests. I 15:00 - 16:00 1.00 CASE P TIE62 RBIH and reset the Champ Packer at 11,386' and test casing to 3,500- si for a rock-solid test, charted 30-minutes. 16:00 - 17:30 1.50 CASE P TIE62 Circulate Bottoms Up, 6-BPM at 880-psi. Dynamic loss rate at 52-BPH, which slowed to 44-BPH with a final circulatin ressure of 1 020- si. 17:30 - 18:00 0.50 CASE P TIEB2 Pump a dry-job, blow down Top-Drive and monitor well. Static loss rate at 23 bph. 18:00 - 00:00 6.00 CASE P TIEB2 POOH with HES Champ PKR. UD 4" HT-38 Drill Pipe in pipe shed. Static loss rate down to 20 bph while POOH. 3/13/2008 00:00 - 03:00 3.00 CASE P TIE62 Continue to POOH with HES Champ PKR. UD 4 HT-38 drill pipe in pipe shed. UD total of 357 joints of 4" HT-38 drill pipe, 40 joints/hr average. Static losses at 20 bph. 03:00 - 04:00 1.00 CASE P TIE62 POOH with HES Champ PKR. UD 9 joints o 4-3/4" drill collars Printed: 3/27/2008 1:53:35 PM . ~ -- BP EXPLORATION Page 17 of 12' Operations Summary Report Legal Well Name: 1-67/T-20 Common Well Name: 1-67/T-20 Spud Date: 11/13/1989 Event Name: WORKOVER Start: 2/29/2008 End: 3/18/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/14/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase ' Description af Operations 3/13/2008 03:00 - 04:00 1.00 CASE P TIEB2 in pipe shed. L/D HES Champ PKR and x/o sub. 04:00 - 06:00 2.00 RUNCO RUNCMP Clear and clean rig floor. C/O bails and elevators. P/U Doyon Torque Turn Casing equipment. R/U rig floor. Prep pipe shed and equipment to P/U completion. Check completion jewelry and tubing. 06:00 - 20:30 14.50 RUNCO RUNCMP RIH new 4-1/2" 12.6# L-80 TC-II com letion. Baker~ok WLEG, XN-nipple, X-nipple, and Baker S-3 4-1/2" x 7" Packer assemblies. Torque-Turn all connections to 3,850 ft-Ibs using Jet-Lube Seal Guard pipe dope. Average fluid loss is 25-BPH. Ran with joint #20 at 07:40-hrs, joint #122 at 12:55-hrs, joint #206 at 19:07 hrs, Joint #237 at 20:50 hrs. Replaced 2 joints in completion string, numbers 21 and 134. Replaced 2 collars on joints number 20 and 133. Had to tighten up collar on joint number 128. 20:30 - 22:30 2.00 RUNCO RUNCMP Hold PJSM with rig crew and HES control line tech. Discuss procedure for RIH with safety valve. P/U HES Dummy BBE SSSV. M/U into completion string. R/U control line spools and rig floor. Purge control lines and install to SSSV. Pressure test control lines to 5000 psi. Hold test for 10 minutes, good test. Secure control lines to tubing with stainless steel bands. 22:30 - 00:00 1.50 RUNCO RUNCMP Continue P/U and RIH with 18 joints of 4-1/2" TC-II completion tubing securing control lines to tubing with one stainless steel band per joint. Static loss rate at 16 bph. 3/14/2008 00:00 - 01:30 1.50 RUNCO RUNCMP Continue P/U and RIH with 18 joints of 4-1/2" TC-II completion tubing securing control lines to tubing with one stainless steel band per joint. Ran a total of 273 joints of 4-1/2", 12.6#, L-80 TC-II tubing; 5 GLM assemblies; 1"X" nipple assembly; 1 Baker S-3 PKR assembly; and tail pipe assembly consisting of 1"X" nipple and 1"XN" nipple assemblies; and 1 WLEG assembly. Used 43 stainless steel bands to secure control lines. All 4-1/2" TC-II connections made up to 3850 ft-Ibs torque with Doyon Torque Turn equipment. 01:30 - 03:30 2.00 RNTBH P TUBHGR P/U FMC 13-5/8" x 4-1/2", TC-II box x box tubinq hanqer assembly and M/U into completion string. Space out control lines and run through tubing hanger. Pressure test tubing hanger control line ports to 5000 psi for 10 minute each, good tests. Wrap and secure control lines on tubing hanger neck. Reconnect control lines to control line spools and pressure test to 5000 psi for 5 minutes. Maintain pressure at 5000 psi and monitor while landing tubing hanger. 03:30 - 04:30 1.00 RNTBH P TUBHGR R/U and RIH with tubing hanger with 165,000 Ibs up weight and 140,000 Ibs down weight in 9.8 ppg brine. RILDS. 04:30 - 08:00 3.50 RUNCO RUNCMP PJSM with rig crew and vac truck operators. Discuss displacement operation and Doyon fluid transfer procedures. R/U and reverse circulate 190 bbis of new 140 deg F 9.8 ppg brine and 290 bbls 140 deg F corrosion inhibited brine. Spot inhibited brine in annulus. Pump pressure- 250 psi at 3 bpm. Initial hole fill required 21-Bbls. 08:00 - 10:00 2.00 RUNCO RUNCMP PJSM. Break off 1502 connection on top of TIW valve, drop dart, M/U 1502 connection. Pressure uo on tubina to 4.000-nsi and chart record for a 30-minute solid test. Bleed tubinq to -osi and shut-in. Pressure up the IA to 3,500-psi and record for a solid 30-minute test. Rapidlv bleed the IA Printed: 3/27/2008 1:53:35 PM . ~ ~ BP EXPLORATION Page 12 of 12 Ope'rations Summary Report Legal Well Name: 1-67/T-20 Common Well Name: 1-67/T-20 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 3/14/2008 08:00 - 10:00 2.00 RUNCO 10:00 - 11:00 1.00 BOPSU 11:00 - 12:00 1.00 BOPSU P 12:00 - 12:30 0.50 BOPSU P 12:30 - 15:00 2.50 WHSUR P 15:00 - 16:30 1.50 WHSUR P 16:30 - 19:00 2.50 WHSUR P 19:00 - 21:30 2.50 WHSUR P 21:30 - 22:30 1.00 WHSUR P 22:30 - 23:30 1.00 WHSUR P 23:30 - 00:00 0.50 RIGD P Spud Date: 11 /13/1989 Start: 2/29/2008 End: 3/18/2008 Rig Release: 3/14/2008 Rig Number: Phase Description af Operations RUNCMP pressure to 0-psi and the DCK shear valve sheared at 900-psi. Pump both ways and the valve is open. RUNCMP Blow down all lines. UD Landing Joint. RUNCMP P/U and install TWC with FMC technician. Test underneath to 2,500- si for 30-minutes. Can not test from the top because the SSSV control lines are run inside the BOP stack and up to the Rig Floor. RUNCMP N/D BOPE; set back BOP Stack and secure on rig stump. RUNCMP FMC and Halliburton techs prepare tubing hanger and SSSV connections and test SSSV lines to 5,000-psi. Well Tender (Pad Operator) called to come inspect and verify the gauges and valves that need to be installed on the tree. RUNCMP N/U Adapter Flange and test to 5,000-psi for 30-minutes. RUNCMP N/U tree and perform final SSSV control line test to 5,000-psi, good test. Fill tree with diesel, stroke valves and test to 5,000-psi recorded for 30-minutes on chart. R/D test equipment. Contact Chuck Scheve with AOGCC and gave 24 hour notice for BOPE test on END 1-21. AOGCC wants update in AM. RUNCMP P/U DSM lubricator and equipment. R/U DSM lubricator and tools. Test lubricator to 500 si, ood test. Pull TWC. Check for pressure. Gauges reading 140 psi on tubing and 100 psi on annulus. R/U bleed tank. Bleed pressure. Pressure bled off immediately. L/D TWC. R/D and UD DSM lubricator and equipment. RUNCMP R/U LRHOS circulating lines. Pressure test lines to 3500 psi, good test. Reverse circulate 15-Bbls diesel freeze protection. Line up and U-tube freeze protection. RUNCMP R/U DSM and set BPV. Pressure test BPV for 30 charted minutes at 1000 psi from below, good test. UD DSM. RUNCMP Blow down lines. Secure cellar. Release rig at 24:00 hrs. Printed: 3/z7/zuu8 1:b:1:'s5 rM 03!12!08 ~4~~UtF1U6i1-~~1- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~u..u 1..1. u N0.4629 Company: State of Alaska ~ F r Alaska Oil & Gas Cons Comm ~t,a~~ ~~~ ~ ~ 1Otl~: Attn: Christine Mahnken -d 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Endicott ; ,.., new...;.,+;,.., na+p RI [`ninr r.~ C-176 12031461 USIT ~ •~ 03/09/08 1 1 1-67lf-20 12014001 USIT - ~, .~ 03/09/08 1 1 E-21B 11661157 MCNL a 06/19/07 1 1 02-35B 11216177 MCNL ~ 02/09/06 1 1 C-34A 11216194 MCNL ~ ~ Q( 05/11/06 1 1 G-08A 11628761 MCNL ~ ~ 05/11/07 1 1 04-01A 11661146 MCNL - 05/15/07 1 1 PLEASt AGKNUWLtUGt titGtlP1 tSY JIIaNING ANU Fit! UFSNINU VIVO I.VYT CAI.n Iv: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ;; 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ ~ ~ ~='~~1~,+ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: • • MEMORANDUM To: Jim Reoa 'k7 P.I. Supervisor I~~~ 4{ ~g~~ FROM: Chuck Scheve Petroleum Inspector State of Al.:;' Alaska Oil and Gas Conservation Commission DATE: Monday, April l4, 2v^C8 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 1-67lC20 DUCK IS UNIT MPI d -67/T20 Src: Inspector NON-CONFi11F.NTi D i Reviewed By: P.I. Suprv f',y2-- r., Well Name: DUCK IS UNIT MPI 1-67/T20 qpI Well Number: 50-029-21985-(?0-00 Chuck Scheve / Inspector Name: Insp Num: mitCS0804I4094316 Permit Number: 189-114-0 "'`~' Inspection Date• 4n4izoo8 Rel Insp Num: • T Packer Depth Pretest Initial 15 Mm 30 Min. 45 Min. 60 Min. ._.~~7rrzo _ _ ,_ Well ~___ _AType Inl H' ' TVD 9s37 ''~ IA zso z8zo ~, z7ao z76o __ _ _ _ ,_. P T ~ 1891140 !T eTest ~ .., _ ;-- _....i... Yp _ SPT Test pSl 2459 25 ! OA 340 -. 670 . ~ _. 670 _ ~ 670 -- _ _ _ _ , _Interv_al_ _ _p/F _ _ Tubing z47o zsoo zsoo zsoo _ _ _ _ _. _ _ _...- NOtes: Pretest pressures were observed 30 minutes and found stable. ~~~~~~ JUL ~ ~ 2Q08 Monday, April 14, 2008 Page I of 1 • l.~ 66 ..~ ~ ~ ~ 7 ~ SARAH PALIN, GOVERNOR ALASSA OII, AI~TD GA5 333 W 7th AVENUE, SUITE 100 CO1~T5FiR`QA'1`I011T COMI~II55IO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. ~~ SAN ~ ~' 2048 PO Box 196612 Anchorage, Alaska 99519-6612 ~~~.I~~ Re: Endicott Field, Endicott Oil Pool, END 1-67/T-20 \' Sundry Number: 308-009 Dear Mr. Reem: 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. DATED this ~Jday of January, 2008 Encl. Sincerelv. ~~~~~~~ G~~ STATE OF ALASKA I1l~d' ALASKA OIL AND GAS CONSERVATION COM~ION ~~~~ APPLICATION FOR SUNDRY APPROVAL~j~~ ~ 20 AAC 25.280 ~ ~~~ 1 ~ ~~~8 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ~ ' ~+ ~B~~II~ii~°a~S ions. 6idmml>siAn ,_,/ U~ Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter S~EO~~~ell ~ X11 ^ Change Approved Program Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration {Alaska) Inc. ^ Development ^ Exploratory 189-114 '' 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21985-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: END 1-67 I T-20 ' Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 034636 ~ 55.1'- Endicott Field / Endicott Pool 92: PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12150 ~ 10614 ~ 11551 10063 11551 See Diagram Casin Len th Size MD TVD Burst Colla se Structural nd r 1 3' 30" 10 ' 1 3' Surface 2498' 13-3/8" 2498' 2498' 5020 2270 Intermediate 10962' 9-5/8" 10962' 9536' 6870 4760 Producti n Liner 1730' 7" 10683' - 12413' 9297' - 10858' 9690 7820 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11444' - 11736' 9966' - 10232' 4-1 /2", 12.6# L-80 10748' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW 'HBBP' packer; Packers and SSSV MD (ft): 10664'; 7" Otis'WD' packer 11655' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ^ Development ®Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: February 28, 2008 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ®WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564-4102 Printed Na David Reem Title Engineering Team Leader Prepared By Name/Number: Signature G Phone 564-5743 Date /- q-~jQ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ?~OP Test ~Atlechanical Integrity Test ^ Location Clearance Other: ~eS ~ W~ ~S~ G-~r ~ ~C~.h~~ Subsequent Form Required: ~~~ APPROVED BY Q~ ../~~ A roved B COM ISSI THE COMMISSION Date U Form 10-403 Revised 06/2006 ___~ ~~. Et~iv V ~,/ O R I G I N A L Submit In Duplicate ?~0~ • by DS Endicott 1-67 Rig Workover Scope of Work: Pull 4 %2" L-80 completion, mill and retrieve packer, Run 7" scab liner from -2700' to -10,700' and and cement. Change out 9 5/8" casing packoffs. Run 4 %" 13Cr-80 completion. MASP: 4000 psi Well Type: Kekiktuk Water Injector Estimated Start Date: February, 2007 Pre-rip prep work: S 1 Drift down to 10,800' and throu h tb tail for Fasdril plu SBHPS. E 2 Set Fasdril plug @ -10695' and in 4 %2" tbg tail (in full joint just below production packer (Ref. 12/10/89 tubing tally). MITT to 4000 psi. MITOA to 3000 psi. Power Jet cut @ 10,634' md, in the top of the 10' pup above the production packer -leave ~8' of stub looking up above collar below Ref: 12/10/89 tubin tall W 3 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well should be secured at this time with a Fasdril lu PPPOT-T & IC. F 4 Circulate well with seawater. Circulate well with KW brine (weight TBD) FP w/ diesel to 200'. Bleed WHP's to 0 psi. O 5 Set a BPV. Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE configured for 3000+ psi MASP (4 preventers). Pressure test to 4000 psi. Annular preventer tested to 3500 psi. Circulate out freeze protection fluid and circulate well to clean kill weight brine through the cut. 2. Pull and LD 4 %" tubing string to the cut. 3. Retrieve SBR, anchor-seal, and mill/retrieve production packer. Clean out wellbore to -11,550' md. 4. Set a retrievable packer 10,800' and and place 50' of sand on top. 5. Run and fully cement 7" scab liner from 2700' to 10,700' and (will tie into existing 7" liner via tieback seal stem). 6. Change-out and test casing packoffs. 7. Drill out shoe-track and PT casing to 4000 psi f/30-minutes. 8. Retrieve packer from 10,800' md. 9. Run RTTS test packer and set 11,300' md. PT casing to 4000 psi f/30 minutes. 10. Run 4-'/2" 13Cr-80 completion with 7" x 4 %2" packer set 11,300' md. 11. Displace the IA to packer fluid and set the packer. 12. Test tubing and IA to 4000 psi. Freeze protect to 200' MD. 13. Set BPV. ND BOPE. NU and test tree. RDMO. TREE: 4-1/16" / 5000 ~meron / Axelson Actuator WELLHEAD: 13-5/8" / 5000 psi /FMC R.T. ELEV = 55.1' B.F. ELEV = 16.1' MAX. DEV. = 41:48 9400' MD 13-3/8", 68#/ft, L-80, Btrs Csg 2498' SAFETY NFISH @ STATION #1 END 1 ~~7 AS OF 04/ FISH @ UNKNOWN DEPTH (11/2 ) SSSV LANDING NIPPLE 1551' OTIS 3.813" I.D.) W/SS V MIN I.D. 2" MIN ID = 3.725" @ 11666' 4-1I2" XN NIPPLE NT80S XO to NT95HS 9551' i-~ Tbg Vol = 162 Bbls. Tailpipe Vol = 1.3 Bbls. 4-1/2", 12.6#/ft L-80, TAILPIPE . TOP OF 7" LINER 10684' 9-5/8", 47#/ft, NT95HS, NSCC 10962' -~ Pff2FORATION SUMMARY REF LOG: CBL ON 12/10/89 ANGLE AT TOPPERF: ??? @ 11444' Note: Refer to Production DB for historical pert dat SIZE SPF INTERVAL ** DATE 3-3/8" 4 11444 - 11454 O 3-3/8" 4 11463 - 11473 O 3-3/8" 4 11448 - 11496 O 3-3/8" 4 11500 - 11506 O 3-3/8" 4 11509 - 11525 O 3-318" 4 11527 - 11552 O 3-3/8" 4 11605 - 11638 O 3-3/8" 4 11510 - 11524 O 3-3/8" 4 11528 - 11540 O 2-7/8" 6 11540 - 11550 O 3-3/8" 4 11702 - 11736 C I " KtY: V = VNGV / (: = I:LUJtL / PBTD 12050' 7", 29#/ft, SM-110, DATE REV BY COMMENTS DATE REV BY COMMENTS ??7 ORIGINALCOMPL. 03/09/06 TE1/TLH WRPRESET(3/3/06) 05/03/00 MAS ADFERF(10/99) 03!16/06 RPFf/TLH WANERSFTYDELET 05/10/05 RAC/TLH GLV FISH (4/12/05) 04/16/06 JCM/PAG WRP PULLED (04/06/06) 11/21/05 MOR/PJC FISH (MCX PLUG) 12/01/05 KSB/TLH MCX FISH CORRECT. 01/20/06 KSBffLH GLV GO (11/24/05) ~3-3/8" SPENT PERF GUN (25' LONG). 1-3/4" FISHING NECK TAGGED PBTD @ 11970' WLM 8!21/94 ENDICOTT UNIT WELL: 1-671 T-20 PERMlT No: 1891140 API No: 50-029-21985-00 SEC T N R E BP Exploration (Alaska) 4-1/2", 12.6#/ft, L-80, TDS (~A S LIFT MA NDRFl_S lCA t°.Ci-???1 S MD TVD VLV LATC PORT DATE 6 4139 4078 DMY RK 0 11/24/05 5 6809 6260 DMY RK 0 4 8686 7715 DMY RK 0 3 9935 8651 DMY RK 0 2 10358 8977 DMY RK 0 1* 10623 9192 DMY RK 0 `hI9Fi VtYS1TF'€ LREi:M (f"'tAI,'~'LiLUCHL PULLING TOOL) • U5E CAll1 IN -FISH -MCX PULLING PRONG ~~~~~~ (2-1/2" x 3/4" OD 11/21/05) - 4-1/2"'X' NIPPLE 10642' OTIS (3.813" I.D.) - TIW SBR (12' long) 10648' (5.438" O.D.) 10664' H 9-5/8" TIW HBBP FKR, ID = 4.00" ~ 10715' H 4-1/2" OTIS X NIP, ID = 3.813" 10736' 4-1/2" OTIS X NIP, ID = 3.813" 10748' 4-1/2" WLEG 10743' ELMD LOGGED ON ??;'??r?? 1119T MARK 11454' SLM FISH: WFD PLUG 8 SETTING TOOL LOST (02/09/06) 11551' CEMENT CAP TOP (?'?;?????) ~- 7" OTIS "W D" PKR 11655' 4-1/2"'X' NIPPLE ~~ OTIS (3.813" I.D.) 1 ~, 4-1/2"'XN' NIPPLE " 11666' OTIS (3.725 I.D.) " 4-1/2 WLEG TREE: 4-1/16" / 5000 ~eron / END 1-6 7 P ro ~s e d Axelson Actua WELLHEAD: 13-5/8" / 5000 psi /FMC (CCL R.T. ELEV = 55.1' B.F. ELEV = 16.1' MAX. DEV. = 41:48 9400' MD 13-3/8", 68#/ft, L-80, Btrs Csg 2498' (~ ~ SSSV LANDING NIPPLE -1500' v-tl ` I I HES HXO (3.813" LD.) W/SSSV MIN I.D. 2" MIN ID = 3.725" @ XXXX' 4-1 /2" XN NIPPLE NT80S XO to NT95HS 9551' -~ Fully Cemented 7", 26#/ft, BTC-MOD, L-80 TOP OF 7" LINER 10684' _~ 9-5/8". 47#/ft. NT95HS. NSCC 10962' PERFORATION SUMMARY REF Lam: CBL ON 12/10/89 A NGLE AT TOP FERF: ??? @ 11444' Note: Refer to Production ~ for historical pert dat SIZE SR= INTERVAL *' DATE 3-3/8" 4 11444 11454 O 3-3/8" 4 11463 - 11473 O 3-3/8" 4 11448 - 11496 O 3-3/8" 4 11500 - 11506 O 3-3/8" 4 11509 - 11525 O 3-318" 4 11527 - 11552 O 3-3/8" 4 11605 - 11638 O 3-3/8" 4 11510 11524 O 3-3/8" 4 11528- 11540 O 2-7/8" 6 11540 - 11550 O 3-3/8" 4 11702 - 11736 C 4-1/2" HES X NIP, ID= 3.813" 7" x 4 1/2" S-3 PKR, ID = 3.88" 4-1/2" HES X NIP, ID = 3.813" ~4-112" HES XN NiP, ID = 3.725" f F- 4-1/2" WLEG 11197' MARKER 11551' CEMENT CAP 70P ('%'~~'%`li??) ???? CARBOLITE ~- 7" OTIS "WD" PKR 11655' 4-1/2"'X' NIPPLE ~~ OTIS (3.813" I.D.) 11662' ~/ 4-1/2"'XN' NIPPLE 11666' OTIS (3.725" I.D.) " 4-1/2 WLEG KEY: O =OPEN / C = CLOS®/ SOZ=SQU~Z® PBTD 12050' 7", 29#/ft, SM-110, ~-~ DATE REV BY COMMENTS DATE REV BY COMMQVTS ??? ORIGINAL COMPL. 03/09/06 TEL/TLH WRPRESET (3/3/06) 5/03/00 MAS ADPERF (10/99) 03/16/06 RPHI/TLH WAN6~ SFTY DEL 5!10/05 RAC/TLH GLV FISH(4/12/OS) 04116/06 JCM/PAG WRPRILLED(04/06/06) 1/21!05 MOR/PJC FISH (MCX P1UG) 2/01 /05 KSB/TLH MCX FISH CORRECT. 1/20/06 KSB(TLH GLV GO (11 /24/05) ~3-3/8" SPENT PERF GUN (25' LONG). 1-3/4" FISHING NECK TAGGED PBTD @ 11970' WLM 8/21/94 END~OTT UNIT WELL: 1-67 / T-20 PERMfI- No 1891140 API No: 50-029-21985-00 SEC T N R E BP Exploration (Alaska) -4-1/2", 12.6#/ft, L-80, TCII -2700' 7" x 9 5/8" ZXP LINER PKR GAS LIFT MANDRELS (KBG-21 MD TVD VLV LATCH R'~RT DATE DCR RK 0 ' DMY RK 0 DMY RK 0 DMY RK 0 DMY RK 0 DMY RK 0 ' Endicott 1-67/T-20 (PTD #1891140) Internal Waiver Cancellation -... e 'Ké2[Q '3(/1ID" Sub.iect: Endicott 1-67/T-20 (PTD #1891140) Internal Waiver Cancellation - Trouble Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Thu, 16 Mar 2006 07:02:03 -0900 To: "AOGCC - Winton Aubert (E-mail)..<wintol1_élubcrt@admin.state.ak.us>. jimJcgg@admin.state.ak.us, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "END, Operations Lead Tech" <ENDOperationsLeadTech@BP.com>, END/BAD Arca Manager <ENDBADAreaManager@BP.com>, "END, Wellhead Tech" <.ENDW ellhcadTech@BP.com> CC: "NSlJ, ADW Well Intcgrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "NSlJ, ADW WI Tech" <NSUADWWlTech@BP.com>, "Austin, Paul A" <Pau1.A.Austin@BP.com>, "McMullen, John C" <McMullJC@BP.com> e All, An internal waiver was issued for a PC Leak on Endicott well 1-67/T -20 (PTO #1891140) on 08/26/04. The well no longer passes required compliance testing. The well is currently shut-in and secured. Options to prove tubing integrity will continue to be worked. Until that time, the well will remain shut-in and the waiver cancelled. Notification will be sent to the AOGCC to cancel the corresponding sundry. The well is reclassified as a Trouble well. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Thank you, }lnna CDu6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 1 of 1 3/17/2006 12:53 PM · .. e e ò BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 March 16,2006 RëCë/V£D MAR 2 2 ' Alaska Oil & G 2006 as Cons. C . Anchor,Ð OIrtrn/ssion {Je Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 Subject: END1-67/T-20 (PTD 1891140) Application for Cancellation of Sundry # 304-085 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 304-085. The sundry was for continued water injection with a production casing leak. The well will remain shut-in until compliance testing is complete and an administrative approval is submitted and approved. With the cancellation of the sundry, the well will be removed from the Monthly Injection Report. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincer~, . ~- /', t s:;k</~\A¡"cÂ.- ( ¡ ~ ~ .....,.......~.v..,"',..· . Anna Dube, Well Integrity Coordinator Attachments Application for Sundry Cancellation form 10-404 STATE OF ALASKA a ALA_OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 55.1 KB 8. Property Designation: ADL-034636 11. Present Well Condition Summary: Total Depth measured 12150 true vertical 10613.87 Effective Depth measured 12050 true vertical 10520.98 Casing Conductor Surface Production Production Liner Liner Length 64 2459 9512 1411 13 1458 Size 30" Conductor 13-3/8" 68# L-80 9-5/8" 47# NT80S 9-5/8" 47# NT95HS 4-1/2" 12.6# L-80 7" 29# SM-110 Perforation depth: Measured depth: 11444 - 11506 True Vertical depth: 9966.24 - 10022.37 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 prèssure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Contact Anna Dube / Joe Anders Printed Name Anna Dube Signature r" \;,;;:-~ Form 1 0-404 Revised 04/2004 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic feet feet feet feet MD 39 - 103 39 2498 39 - 9551 9551 10962 11655 - 11668 10684 - 12142 11510 - 11550 10026 - 10062.28 4-1/2" 12.6# StimulateD Other 0 Cancel Sundry WaiverD Time ExtensionD 304-085 Re-enter Suspended Well D 5. Permit to Drill Number: 189-1140 6. API Number: 50-029-21985-00-00 9. Well Name and Number: Exploratory Service ~ CI.I ~ Q) 1-67/T-20 » 10. Field/Pool(s): Endicott Field/ Endicott Oil Pool Plugs (measured) Junk (measured) TVD 39 - 103 39 - 2497.96 39 - 8417.02 8417.02 - 9536.43 10157.74 - 10169.6 9297.47 - 10606.43 11702 - 11736 10200.62 - 10231.58 L-80 4-1/2" BBE SCSSSV 4-1/2" TIW HBBP-R Packer 7" Otis WD Packer 10714 11970 ~ n 3 3 ëï;' en 15' == Burst Collapse 4930 2270 6870 4760 8150 5080 8430 7500 11220 8510 39 - 10748 1551 10664 11655 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 11086 1 00 shut-in &&- Title Well Integrity Coordinator Phone 907-659-5102 n R I h J f\1 ^ I Tubing pressure 2310 Service WINJ r:z W DSP L 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG 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: 304-085 Date 3/16/2006 R8DMS BFL MA'\ü , " "~", ~. Submit Original Only . n.2 ç) 1006 \ STATE OF ALASKA _ ALA-, OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 55.1 KB 8. Property Designation: ADL-034636 11. Present Well Condition Summary: Total Depth measured 12150 true vertical 10613.87 Effective Depth measured 12050 true vertical 10520.98 Casing Conductor Surface Production Production Liner Li ner Perforation depth: Length 64 2459 9512 1411 13 1458 Size 30" Conductor 13-3/8" 68# L-80 9-5/8" 47# NT80S 9-5/8" 47# NT95HS 4-1/2" 12.6# L-80 7" 29# SM-110 Measured depth: 11444 -11506 True Vertical depth: 9966.24 - 10022.37 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Contact Sharmaine Vestal Printed Name Sh, ac~al", V"lal , -k Signa~-?if~ "_ Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development 0 Stratigraphic 0 feet feet feet feet MD 39 - 103 39 - 2498 39 - 9551 9551 - 10962 11655 - 11668 10684 - 12142 11510 - 11550 10026 - 10062.28 4-1/2" 12.6# 4-1/2" BBE SCSSSV 4-1/2" TIW HBBP-R Packer 7" Otis WD Packer Stimulate D Other 0 Set packer plug Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: » ¡;- ~ Q) S? Exploratory Service 9. Well Name and Number: p 189-1140 6. API Number: 50-029-21985-00-00 1-67/T-20 » :::I ::r 0 n .... 0 ~ I» :::I CD = n = m ~ 0') 0 ëï;' en 15' :::I 10. Field/Pool(s): Endicott Field/ Endicott Oil Pool Plugs (measured) Junk (measured) TVD 39 - 103 39 - 2497.96 39 - 8417.02 8417.02 - 9536.43 10157.74 - 10169.6 9297.47 - 10606.43 11702 - 11736 10200.62 - 10231.58 L-80 10680 11970 Burst Collapse 4930 2270 6870 4760 8150 5080 8430 7500 11220 8510 39 - 10748 1551 10664 11655 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 11086 100 shut-in Title Data Mgmt Engr Phone 564-4424 Form 10-404 Revised 04/2004 R8DMS 8FL MAR 2.3 1006 .~submit Original Only 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tubing pressure 2310 Service P WINJ P WDSPL Date 3/16/2006 e e 1-67/T-20 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 3/1/2006 ***WELL SI ON ARRIVAL,*** (SET WRP} LOCATE TUBING TAIL @1070TSLM, ELMD 10743' CORRECTION OF +34', ***CONTINUED ON WSR 3-2-06*** 3/2/2006 ***CONTINUED FROM 3-1-06**** MADE ONE ATTEMPT TO SET WRP, MIS-FIRE DUE TO BAD EFI, LAID DOWN EQUIP UNTIL FURTHER NOTICE PER BP REP ***NOTIFY OPER*** 3/3/2006 ***CONTINUED FROM 3-2-06 WSR*** SET 4.5" WRP ON E-FIRE @ 10680' MD ***WELL LEFT S/I*** FLUIDS PUMPED BBLS 1 I ::::L 1 RE: ENDI-67 (PTD 1891140) MIT Form e e K~ /Ü(,~r£: Sub.iect: RE: ENDI-67 (PTD 1891140) MIl' Form From: ";\1Sl.J, AD\V WelllnLegriLy Engincer" <NSLJADWWclllntcgrityEngineer@BP.com> Date: Tuc, 13 Dee 2005 12:05:55 -0900 To: Jamcs Regg <jim_regg@admin.state.ak.us>, "Holt, Ryan P (VECO)" <Ryan.Holt@:BP.com> cc: winton .<luhert@admin.state.ak.us, Rohert Fleckenstein <boh_...llcckenstein@admin.staLe.ak.us>, tom_}naundcr~l;admin.state.ak.us, "ì'\SU, AD\V Well Integrity Engineer" ·<:NSUADWWclIrntegrityEngincer@BP.com>, "Engel, Harry R" <EngcIHR~~~BP.com>, "NSU, ADW Well Operalions Supervisor" <'::NSUADWWellOperationsSupervisor(q;BP.com>, "Rossberg, R Steven" <RosshcRS@BP.com>, "McMullen, John C" <McMuII.lC@ßP.com>, "Dube, Anna T" <Anna.Dubc@BP.com>, "NSU, ADW WL & Completion Supervisor" <NSl.; AD WWL&C omplct ionS upervisor@BP.com> Hi Jim. Good catch. We've scheduled an IBP for this well. We'll use an IBP or equivalent in the future and test the entire tubing string. Joe 1-907-659-5102 .,,'-, 11. !r.! i!\I\$;;: I' (,¡ {\ ·,~\.;61)G'>J ;-lC t_: e u From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Monday, December 05,2005 10:32 AM To: Holt, Ryan P (VECQ) Cc: winton_aubert@admin.state.ak.us; Robert Fleckenstein; tom_maunder@admin.state.ak.us; N5U, ADW Well Integrity Engineer Subject: Re: ENDl-67 (PTD 1891140) MIT Form Endicott 1-67 is operating under a sundry waiver approval (#304-085) allowing continued water injection with a known production casing leak. Basis for our waiver was competent tubing. My understanding from discussing the most recent MIT with Chuck Scheve (AOGCC Inspector that witnessed the test) is that this was not a valid MIT; following was included Remarks section of his inspection report: "This well has a Known IA leak. MITT performed to verify tubing integrity. A plug had been set in the X nipple at 10642 MD, the packer is at 10664 leaving the 12' seal bore untested. When questioned as to why the plug wasn't set in the nipple at 10715 The BP rep Ken Bullock indicated they couldn't get a test with the plug set there." Well schematic shows two different X-nipples in tubing tail- 10715' and 10736'; test plug was instead set in a X-nipple at 10642' (above the tubing tail). How can you assume the well has competent tubing (and packer) when the MIT does not evaluate the bottom 320 feet of tubing, including the area most susceptible to a tubing leak (SBR and packer)? Given the fact that the Commission has deemed this invalid, what is BP's next step for Endicott 1-67? Jim Regg AOGCC lof2 12/13/2005 12:50 PM RE: ENDl-67 (PTD 1891140) MIT Form e e Holt, Ryan P (VECO) wrote: Jim, Winton, Bob, and Tom, Please see the attached MIT form for END 1-67, an MIT-T passed for Waiver / Sundry Compliance on 11/27/05. The test was witnessed by Chuck Scheve. Let me know if you have any questions, «MIT END END1-67 11-27-05.xls» Thanks, Ryan Holt Well Integrity Tech. Pager 4236-786 Office 659-5524 2 of2 12/13/2005 12:50 PM e e Suh.iect: Rc: E1\DI-67 (PTD 1891140) MIT Form From: James Regg <jim.Jcgg(q;admin.statc.ak.us> Date: Man, 05 Dee 2005 10:32:22 -0900 To: "Holt, Ryan P (VECO)" <Ryan.Holt@)bp.com> CC: winton_..aubert@admin.stale.ak.us, Robert Fleckenstein <bob__t1cckenstein@admin.state.ak.us>, tom._.maundcr@admin.statc.ak.us, "NSU, ADW Well Integrity Engineer" <NSLTAD\VW cllJntegrityEngineer@bp.com> \ \ ....f'" \1.. 1. \V? I'Î I' '(:ß1" l . , Endicott 1-67 is operating under a sundry waiver approval (#304-085) allowing continued water injection with a known production casing leak. Basis for our waiver was competent tubing. My understanding from discussing the most recent MIT with Chuck Scheve (AOGCC Inspector that witnessed the test) is that this was not a valid MIT; following was included Remarks section of his inspection report: "This well has a Known IA leak. MITT performed to verify tubing integrity. A plug had been set in the X nipple at 10642MD, the packer is at 10664 leaving the 12' seal bore untested. When questioned as to why the plug wasn't set in the nipple at 10715 The BP rep Ken Bullock indicated they couldn't get a test with the plug set there." Well schematic shows two different X-nipples in tubing tail- 10715' and 10736'; test plug was instead set in a X-nipple at 10642' (above the tubing tail). How can you assume the well has competent tubing (and packer) when the MIT does not evaluate the bottom 320 feet of tubing, including the area most susceptible to a tubing leak (SBR and packer)? Given the fact that the Commission has deemed this invalid, what is BP's next step for Endicott 1-67? Holt, Ryan P (VECO) wrote: SC/\NNEJ (\ " ~,~ /0 ~ ,I Jim Regg AOGCC ì Jim, Winton, Bob, and Tom, / Please see the attached MIT form for END 1-67, an MIT-T passed for Waiver / Sundry Compliance ft, on 11/27/05. The test was witnessed by Chuck Scheve. Let me know if you have any questions, IZ/7{0'5 - Verl-x,,( reSftM~ b-tvv\ ,Je A-rikr<; f4 "vt . ) fu:1 t (B,o)· . } «MIT END END1-67 11-27-05.xls» Thanks, Ryan Holt Well Integrity Tech. Pager 4236-786 Office 659-5524 ~ (,J; ¿ ( k Çz{tJ-tl.er- _ølt12tlttk¿J Jfj 8p ~'J o K<?fl) l/?/oÇ- 1 of 1 12/5/2005 10:33 AM MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve Petroleum Inspector DATE: Wednesday, November 30,2005 SUBJECT:. Mechanic!\Untegrity Tests BP EXPLORATION (ALASKA) INC 1-671T20 DUCK IS UNIT MPI1-67/T20 n,j\ \L\' ~\¿\ TO: ~~~ S~:;~isor R~fI Src: Inspector Reviewed By: P.I. Suprv :J £,e- Comm Well Name: DUCK IS UNIT MPI 1-67/T20 API Well Number 50-029-21985-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS051127144930 Permit Number: 189-114-0 Inspection Date: 11/27/2005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 1-671T20 fType Inj. I N I TVD ! tt Z'SS- IA ! 100 I 100 I 100 I 100 i ! i I i I P.T. 11891140 ITypeTest! i Test psi I '2313.75 OA I 50 I 50 ! 50 I 50 I 1 i I J:,~ Tubing I í I I ! i Interval REQVAR P/F _JBe.-- 20 I 3660 3660 3660 Notes This well has a Known IA leak. MITT perfonned to verify tubing integrity. A plug had been set in the X nipple at 10642 MD, the packer is at 10664 leaving the 12' seal bore untested. When questioned as to why the plug wasn't set in the nipple at 10715 The BP rep Ken Bullock indicated they couldn't get a test with the plug set there. ~e a~ch.eej· 'ßP }ºt.CA¿S.JeJ +-t) n 7 , \ J Q&'),.J't"<";..> V ia ~<¡,I c4l.ted ¡ Z( 5"'10 5" NON-CONFIDENTIAL Wednesday, November 30, 2005 Page 1 of 1 TREE: 4-1/16" /50001' Cameron / Axelson Act WELLHEAD: 13-5/8" / 0 psi / FMC (CCLI SAFET.ES: ... PROD eSG LEAK; 1M ITS: MAX lAP = 500 PSI, OAP = 1000 PSI (WAIVER 08/26/04)'" "'ASH @ STATION #1 AS OF 04/12/05*** END1-67 R.T. ELEV = 55.1' B.F. ELEV= 16.1' MAX. OEV. = 41:48 . 9400' MO' 13-3/8", 68#/ft, L-80, Btrs Csg 12498' 1 >~ 9-5/8", 47#/ft NT80S XO to NT95HS I 9551' I > - Tbg Vol = 162 Bbls. Tailpipe Vol = 1.3 Bbls. Liner to Top Perf Vol = 26 Bbls ~/ lAg""':' ~ I ~ ./ £\ç"" ¡\itý¡-- -r // I ·7 ( -' ~+- \ "- TOPOF7"LlNER "., .¡"X . ~-_.....:. I I e\l a:lviPlj\'"'(f ~ (J I) 10684' 'Çlf-" I I 9-5/8", 47#/ft, NT95HS, NSCC 110962' I > .. ~ORAnONSUMMARY REF LOG: CBL ON 12/10/89 ANGLEATTOP~:??? @ 11444' Note: Refer to Production DB for historical perf dat SIZE SPF INTERVAL .. DATE 3-3/8" 4 11444-11454 0 3-3/8" 4 11463 - 11473 0 3-3/8" 4 11448 - 11496 0 3-3/8" 4 11500 - 11506 0 3-3/8" 4 11509-11525 0 3-3/8" 4 11527 - 11552 0 3-3/8" 4 11605-11638 0 3-3/8" 4 11510-11524 0 3-3/8" 4 11528-11540 0 2-7/8" 6 11540-11550 0 3-3/8" 4 11702 - 11736 0 .. KEY: 0 = OPEN / C = CLOSED / SQZ=SQUEEZE PBTD 7", 29#/ft, SM-11 0, I 12050' I I I -- ,. DATE RBI BY COMMENTS 09/11/95 JTP MILL & FCO 12/06/96 DAV ADÆRF 05/01/99 DBR SANDBACKI~ 05/03/00 MAS AD~(10/99) 08/26/04 ATDffiF WAIVERSFTY NOTE - ---G-- ~- - SSSYJANOIN§Jo.IIPPLE .- ~ 551,-1 OTIS (3.813" J.D.) W/SSSV MIN 1.0.2" ... -- -- 4-1/2", 12.6#/ft, L-80, TDS GAS LlFTMANDR8.S (CAMCO-???) S MD 1VD VLV LATCf- PORT DATE 6 4139 4078 DOME RK 16 04/12/05 5 6809 6260 DMY RK 0 4 8686 7715 DMY RK 0 3 9935 8651 DMY RK 0 2 10358 8977 DMY RK 0 1* 10623 9192 DMY RK 0 *FISH ON ST#1 LATCH (7" EXT. + GLOBAL PULLING TOOL) - USE CAUTION ~ ~ ...... 4-1/2" 'X' NIPPLE OTIS (3_813"1.0.) I 10642,1 --- :-;.¡ ::jTlW SBR (12'long) I 10648,1 (5.438" 0.0.) _ 9-5/8" PACKER 1 ' I " ::':// TIW (HBBP) (4.00"1.0.) 10664 :;; - 4-1/2", 12.6#Ift L-80, TAILPIPE I 4-1/2" 'X' NIPPLE I I OTIS (3.813"1.0.) . 10715' 4-1/2" 'X' NIPPLE I OTIS (3.813"1.0.) . 10736' 4-1/2" WLEG I 10748' EaT ELMO I 10743' 111197' I 11,551 I 1 MARKER F""'==I ~ [ Cement cap top Carbolite ..- 7" OTIS "WO" PKR 4-1/2" 'X' NIPPLE ~ OTIS (3.813" 1.0.) ~~ 4-1/2" 'XN' NIPPLE ~ OTIS (3.725" 1.0.) ..- 4-1/2" WLEG /11655' I 111662' I 111666' 1 1116611' I ~3-3/8" SPENT PERF GUN (25' LONG). 1-3/4" FISHING NECK T AGGEO PBTO @ 11970' WLM 8/21/94 DA TE RBI BY COMMENTS 05/10/05 DTRlTLH GLV C/O (4/11/05) 05/10/05 RAC/TU GLV FISH (4/12/05) ENDICOTT UNIT WB..L: 1-67/T·20 ÆRMIT No: ?? API No: 50-029-21985-00 SECTNRE BP Exploration (Alaska) e Wireline Work Request Alaska Wells Group .512/14/0 END1 -67 Distdbution__n __ -----~---- Wireline (2) H2S Level: ..................................................................... No Data Available __._ ______....__..-. _u_ u________ -- -------- -.. -------. ..---- --- ------- --..----.-....-.------- Well: EN D1-67 Date: 11/16/05 lOR 370 AWGRS Job Scope: AFE: ENR01WL67-M Engineer: Andrea Hughes WBL Cat. REG COMPL PRESSURE TEST (MAl NT) Problem Description END1-67 is a PWI in need of waiver compliance testing. The purpose of this procedure is to set a TTP and MITT. Initial Problem Review > 10/21/03: Set TTP @ 10642' MD > 10/22/03: MIT-T Passed to 3800 psi Remedial Plan - WIRELlNE ACTION Obj: Waiver Compliance Testing 1. S:Set a TTP in X Nipple @ 10736' MD, MITT to 3800 psi; if passes pull TTP. " . ·~ MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg V ( P.I. 8upel'visor +,,~ II /c{OÇ DATE: Wednesday, November 16, 2005 SUBJECT: MechanicaJlntegrityTests BP EXPLORATION (ALASKA) INC 1-67ìT20 DUCK IS UNIT MPI 1-67ìT20 \ <69 -I If FROM: John Crisp Petroleum Inspector 8rc: Inspector Reviewed By: P.I. Suprv .:J'ße- Comm NON-CONFIDENTIAL Well Name: DUCK IS UNIT MPI 1-67/T20 API Well Number 50-029-21985-00-00 Inspector Name: John Crisp Insp Num: mitJCr0511 13155202 Permit Number: 189-114-0 Inspection Date: 11/12/2005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 11-67ìT20 Type Inj. I w I TVD 9729 IA i 0 3000 1660 I 1290 P T ! 1891140 TypeTest I SPT I Test psi 2432.25 OA I 20 130 100 I 100 . . i , Interval REQVAR P/F F Tubing I 2400 ¡ 2490 I 2470 I 2470 i Notes 35 bbl's pumped to attempt test. Last 5 bbl's pumped @ .8 bpm 3000 psi. which is liquid leak rate in this IA. --¡¿ c;+- ~)i(}l.t-étA tv;u,,-e bee.'\. Cl ,A/I.;ÞT -I SU'iltl.í~::t1-- 324 - ~5 ) &f ,1-ò-h'h'eð -e¡~JL /[,( H7(OÇ (N4c.cJ\k'tj.) :f.R ~'j per- h,j ,~~l~IÀ~I\\~b--f . ""'W1\!!t t!~¡,) F c ,,~ (~ ,~ Wednesday, November 16, 2005 Page 1 of 1 .......-. ~~ ,-... - ,..... -. ,.... .... --... ~.................. J ----....... -"- ... .......---.., .&....J....__... """.... _v \... .. e e ... Subject: Re: ENDI-37íP-24 (PTD 18709(0) CMIT-TxlA, E~DI-67rr-20 (PT E]\JL>4-48/1(-43 (PTD 189(970) MIT-JA Forms -- _From: James Regg <jimJcgg@?admin.statc.ak.us> Date: Tue, 15 Nov 2005 10:20:37 -0900 To: "Holt, Ryan P (VECO)" <Ryan.Ho1t@bp.com> CC: wintou_aubert@admin.state.ak.us, bob_flcckenstein(g).admin.state.ak.us, "NSU, ADW Well Integrity Engineer" <NS (J AD WW cllIntcgrityEngincer(q}bp.com>. john __crisp@admin.state.ak.us END 1-67/T-20: Sundry #304-085 requires a MIT-T for this well, not a MIT-IA Jim Regg AOGCC Holt, Ryan P (VECO) wrote: Jim, Winton, and Bob, ~~:~e the attached MIT forms for wells END1-37/P-24 (PTD# 1870900), END1-67fT-20 (PTD# ~ 189114~) & END4-48/K-43 (PTD# 1890970). END1-37AOGCC representiative John Crisp witnessed END1-37/P24 CMIT-TxIA was conducted in advance a Sundry cancellation and AA submission, Based on a apparent passing MIT-IA, we conducted an AOGCC witnessed MIT-IA that failed on END1-67/T-20. Review of the apparent passing MIT-IA revealed a clerical error. END1-67/T-20 has known TxlA comm and an MIT-IA is expected to fail. END4-48/K-43 MIT-IA was conducted post initial injection. Please feel free to call with any questions. Thanks, Ryan Holt Well Integrity Tech. Pager 4236-786 Office 659-5524 «MIT END4-48 11-12-05.xls» «MIT END1-37 1-67 11-12-05.xls» 1 of 1 11/16/20053:53 PM f ( ò BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 March 17, 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: Endicott 1-67/T-20 (PTD 1891140) Application for Sundry Approval for PWI with Slow Production Casing Leak Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for well Endicott 1-67/T -20 requesting approval to continue injection into a water injection well with a slow <,/ production casing leak. If you require any additional information or clarification, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincerely, J~~ Joe Anders, P .E. Well Integrity Coordinator Attachments Application for Sundry Approval form 10-403 Description Summary of Proposal Well bore Schematic 1 9 200 " OR\G\NAL \J-16A. Ç,Þ1/WCÇ> ~ ~:. STATE OF ALASKA (" ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon 0 Alter Casing 0 ChanQe Approved ProQram 0 2. Operator Name: Suspend 0 Repair Well D Pull TubinQ 0 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.10 KB 8. Property Designation: ADL-034636 11. Total Depth MD (ft): 12150 Casing 64 1458 13 9512 30" Conductor 7" 29# SM-110 4-1/2" 12.6# L-80 9-5/8" 47# NT80S 9-5/8" 47# NT95HS 2459 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10042 - 10053.2 10026 - 10038.7 10006 - 10013.3 10017 - 10022.4 10053 - 10062.3 9966 - 9975.3 9983 - 9992.5 November 2612003 Date: ~ ~ --- --' Operation Shutdown 0 PerforateD VarianceŒj Annular Disposal 0 Plug Perforations 0 StimulateD Time ExtensionD OtherD Perforate New Pool 0 Re-enter Suspended WellO 4. Current Well Class: 5. Permit to Drill Number: 189-1140/- Development 0 Exploratory D 6. API Number ,/ 50-029-21985-00-00 StratigraphicD Service ŒJ 9. Well Name and Number: ,/ 1-67/T -20 10. FieJdJPool(s): Endicott Field / Duck Island Oil Pool 39.0 9297.5 10157.7 39.0 8417.0 4.5 " 12.6 # Conductor Liner Liner Production Production Surface Perforation Depth MD (ft): 11444 - 11540 11463 - 11524 11488 - 11496 11500 - 11506 11510 - 11550 11528 - 11454 11540 - 11473 Packers and SSSV Type: 4-1/2" BBE SCSSSV 4-1/2" TIW HBBp.R Packer 12. Attachments: Description Summary of Proposal IX Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: PRESENT WELL CONDITION SUMMARY ITotal Depth TVD (ft): IEffective Depth MD (ft): I Effective Depth TVD (ft): 10613.9 11551 10063.2 Length Size MD TVD top bottom top 39 - 103 10684 - 12142 11655 - 11668 39 . 9551 9551 10962 39 2498 Tubing Size: Packers and SSSV MD (ft): Plugs (md): 11645 Burst Junk (md): 11970 Collapse bottom 103.0 10606.4 10169.6 8417.0 11220 8430 6870 8150 4930 Tubing MD (ft): 39 8510 7500 4760 5080 2270 9536.4 Tubing Grade: L-80 10748 1551 10664 13. Well Class after proposed work: ExploratoryD DevelopmentD 15. Well Status after proposed work: Oil 0 GasD WAG 0 GINJD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Joe Anders, P .E. J~~ Title Phone Conditions of approval: Notify Commission so that a representative may witness Commission Use Only Service [2g Plugged 0 Abandoned 0 WINJ(2g WDSPLD Perpared by Garry Catron 564-4657. Contact Joe Anders I Anna Dube Well Integrity Coordinator 659-5102 3/9/04 I Sundry NU~;;4J - ð B'SV Plu~ I~l~rity .» ì ¡ BOP .Te~tD .'. _. .MechanC¡a'.!f}..tegrity Tert n t\. l,pc.ation cl~,aran~...D t . ¿ 4dd LLtl ft.! -p-" " 14A.AA..1 J~vf ~1?ûC(i-- ~tA..€.H LU tÂ.t ~". g ç t- 'J:~1€ri..r; £'0 eU €-r. f''y,", ~ ' Other: p '~I rv . Th 1 t-v: e-t~{ t- tot-co 'J.t?C{¡tS. I~? f to!/. C1" (' e~ yu V'~' S &. ?~{ 21)0&, . Subsequ tFor Req : 0 R I GI NAb . ~~ "./ . BY ORDER OF Approved by: l ./I. ' --- ~ 1'111&1' D ~fI';hTHE COMMISSION Date:'~ (J V Form 10-403 Re 2/2003 ~1lN" IUn'" . lUU 1J SUBMIT N DU LlCATE (' (" 1-67 IT -20 Description Summary of Proposal 03/17/04 Problem: Produced Water Injector with slow production casing leak Well History and Status: Endicott weIl1-67/T-20 (PTO 1891140) has a slow production casing leak. An MITIA failed on 9/13/03. Mechanical integrity tests indicate competent tubing, packer, and surface casing. Recent Well Events: > 09/13/03: MITIA Failed, Witnessed by Lou Grimaldi > 09/17/03: MITIA Failed, loses 380/180 psi at 15/30 minutes > 09/22/03: MITIA Failed, loses 450/150 psi at 15/30 minutes > 09/22/03: PPPOT-T Passed, IC Furmatite packed > 09/23/03: MITOA Passed to 1500 psi / > 10/21/03: SetTTP @ 106421 md > 10/22/03: MIT-T Passed to 3800 psi / > 10/23/03: Pulled TTP ,r'" > 01/02/04: LNFT-IA Passed > 01/11/04: MIT-OA to 3360 Failed, broke down shoe at 3300 psi (no LLR /' recorded) > 01/14/04: LLR-OA = 6 gpm @ 3800 psi. / > 01/23/04: Set TTP @ in upper X-Nip. To secure well pre-CTO. / > 02/04/04: CITOA Passed to 3360 psi, .5 bbls over 30 min to maintain pressure. This Sundry request is to allow for continued water injection in this well. The following supports the request: . An MIT-Tubing passed to 3800 psi on 10/22/03, indicating competent tubing. . A CIT -OA passed to 3360 psi on 02/04/04, indicating surface casing is capable of withstanding injection pressure. . Pressure and injection rates will be monitored and recorded daily and checked for indications of a tubing or surface casing leak. Proposed action plan: ! <' 1. Allow well to continue Water injection. 2. Record wellhead pressures and injection rates daily. 3. Perform annual CIT -OA. 4. Perform 4-year MIT-Tubing. 5. Stop injection and notify the AOGCC if there is an indication of a loss of tubing or casing integrity. R.T. ELEV = 55.1' , B.F. ELEV = 16.1' 'I, MAX. DEV. = 41 :48 9400' MD I 2498' I 13-3/8", 68#/ft, L-80, Btrs Csg 9-5/8", 47#/ft NT80S XO to NT95HS I 9551' Tbg Vol = 162 Bbls. Tailpipe Vol = 1.3 Bbls. Liner to Top Perf Vol = 26 Bbls TOP OF 7" LINER I 10684' 1 >-.4. >- >- 9-5/8", 47 #/ft , NT95HS, NSCC I 10962' I >- PERFORATING SUMMARY Ref. Log: CBL (12/10/89) SIZE SPF 3-3/8" 4 3-3/8" 4 3-3/8" 4 3-3/8" 4 3-3/8" 4 3-3/8" 4 3-3/8" 4 3-3/8 4 3-3/8" 4 2-7/8" 6 INTERV^L 11,444' - 11,454' 11,463' - 11,473' 11 ,488' - 11 ,496' 11,500' - 11,506' 11,509' - 11,525' 11,527' - 11,552' 11,605' - 11,638' 11,510' - 11,524' 11,528' - 11,540' 11,540 - 11,550' ST^TUS Open Open Open Open Sqzd Sqzd Sqzd Open Open Open I I I Below "WD" I . 3-3/8 4 11.702'-11.736 Open \ PBTD 7", 29#/ft, SM-11 0, Btrs-TKC Date By 9/11/95 JTP 12/6/96 DAV 5/1/99 DBR 5/3/00 MAS I 12050' I I 12142' I Comments MILL AND FCO AddPerf TREE: 4-1/16" / 5000 psi I \t '\ron I Axelson Actuator WELLHEAD: 13-5/8" / 5000\. FMC (CCl) 0-< SSSV LANDING NIPPLE 1551' I OTIS (3.813" 1.0.) W/SSSV MIN 1.0. 2" -< 4-1/2", 12.6#/ft, l-80, TDS GLM's (CAMCq, (1-1/2" RK Latch) No. TVDSS MD-BKB #6 4078' 4139' #5 6260' 6809' #1 7715' 8686' it3 8661' 9936' #2 8~77' 10358' #1 9192' 10623' 1 0642' 1 I 1071fi' I I I I 11197' I I 1 0736' I 10748' I 10743' I I 11,551 I I I I I I 11655' I 11662' 111666' I 11ññR' ~ » I ~ 3-3/8" SPENT PERF GUN (25' LONG. 1-3/4" FISHING NECK TAGGED PBTD @ 11970' WLM 8/21.-3/ ENDICOTT WELL: 1-671 T-20 API. NO. 50-029-21985 COMPLETION DIAGRAM Post Sandback, add perfs I Add perfs (10/99) BP EXPLORATION (ALASKA), INC TIW SBR (12' long) I 10648' I (5.438" 0.0.) 9-5/8" PACKER I TIW (HSSP) (4.00" 1.0.) 10664' 4-1/2", 12.6#/ft L-80, TAILPIPE 4-1/2" 'X' NIPPLE OTIS (3.813" 1.0.) 4-1/2" 'X' NIPPLE OTIS (3.813" 1.0.) 4-1/2" WLEG -< ...c: 4-1/2" 'X' NIPPLE OTIS (3.813" 1.0.) ¡ ~ J~ 2{< 4.. ~:-- ~ I ~ \< l. EOT ELMO MARKER ~].. Cement cap top Carbolite ~~ 7" OTIS "WD" PKR t. 4-1/2" 'X' NIPPLE ~ OTIS (3.813" 1.0.) 4-1/2" 'XN' NIPPLE t Plug' ~ OTIS (3.725" 1.0.) J'L(' ,,~ 4-1/2"WLEG ~ 0 \ l{ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jì m Regg K.&, (¡ III <) 104' DATE: January 11, 2004 P.I. Supervisor { '{ SUBJECT: Mechanical Integrity Tests FROM: Jeff Jones BPXA Petroleum Inspector MPI 1-671T20 DIU Endicott NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Weill 1-671T20 I Type Inj.1 N I T.V.D. I 9255 Tubing 2325 2325 2325 2325 Intervall V P.T.D.I 189-114 I Type testl P I Test psi I 2314 Casing 60 65 60 60 P/F I F OA 0 3300 640 240 Notes: 4.8 BBLS 60/40 methanol pumped. Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover P = PRODUCED WATER D= Differential Temperature Test 0= Other (describe in notes) Test's Details January 11,2004: I traveled to BPXA's Endicott field to witnçss an MIT on welll-67/T20. Bill Rochin~ was the BPXA representative for the tests today and he indicated that the MIT on the OAof we111-67 /T20 was required to receive a variance to operate this well with a known IA casing leak. The pretest pressures were monitored for 30 minutes and found to be stable. The standard annulus pressure test was then performed with the OA failing the MIT. Summary: I witnessed an unsuccessful MIT on the OA of BPXA's Endicott Field well 1-67/T20. 1 well house was inspected; no exceptions. M.I.T.'s performed: 1 Number of Failures: 1 Total Time during tests: 2 hrs. Attachments: !lQ!!! ~ Tom Maunder (AOGCC) ~tt~li\~!NJEl> JAL\N ~¿~ ~ 200~, MIT report form 5/12/00 L.G. MIT DIU 1-67 1-11-04.xls 1/15/2004 * ' { ( Prt l '6(1- 1(4 2003-1120_scP_Endicott_1-67_no_MI_wga.txt subject: Re: Endicott wells with sustained casing pressure Date: Thu, 20 Nov 2003 11:22:56 -0900 From: winton Aubert <winton-Aubert@admin.state.ak.us> organization: AOGCC To: "Robertson, Daniel B (Alaska)" <RobertDB@BP.com> CC: James B Regg <jim_regg@admin.state.ak.us>, sarah H palin <sarah_palin@admin.state.ak.us>, Daniel Seamount <dan_seamount@admin.state.ak.us> Dan, upon review of BPXA submitted information and commission files on Duck Island well 1-67/T20, AOGCC concludes that MI (injection) is not appropriate. The apparent production casing leak (depth unknown) suggests that depth control of gas injection is compromised. If you wish to inject water into 1-67/T20, please submit a sundry (Form 10-403) for commission approval. Thank you, winton Aubert AOGCC 793-1231 <i!. ... page 1 """'/ ¡~~rÌò¡Iit:~')i jAW 2; ij 2004. ~\~/~Ð~m~I&;:,I\" It RE: Endicott Monthly Injection Report Subject: Date: From: To: CC: RE: Endicott Monthly Injection Report Fri, 3 Oct 2003 12:49:06 -0500 "Millholland, Madelyn A" <millhoma@BP.com> Jim Regg <jim_regg~admin.state.ak.us> Winton G Aubert <winton_aubert@admin. state, ak.us>, "END, Production Coordinator" <ENDProductionCoordinator@BP.com>, "Robertson, Daniel B (Alaska)" <RobertDB~BP.com> Jim, I spoke with Steve Schultz, the Production Coordinator up at Endicott, regarding 1-76/T-20. It was shut-in on the 25th. A wireline rig is being brought in to secure the well and within the next day or so leak detection work will be run. Steve Schultz will get back to you today with more detailed information. I believe Dan Robertson left a message earlier this week with Winton Aubert regarding the status and the plans for 1/67/T-20. Please feel free to give me a call if you have further questions. Madelyn Madelyn Millholland P,O, Box '198612 900 E. Benson Bird, Anchorage, AK 99519-68t2 Phone: 90'7.564,5234 Fax: 907,564-4441 Inf~eroffice Mail: MB 4~2 Anchorage, AK emaii ' millhoma~bp,com ..... Original Message ..... From: Jim Regg [mailto:jim_regg@admin.state.ak. us] Sent: Thursday, October 02, 2003 6:04 PM To-' Millholland, Madelyn A Cc: Winton G Aubert Subject: Re: Endicott Monthly Injection Report Endicott Well 1-67/T20 failed MITs (AOGCC witnessed) on 9/13/03 and again on 9/19/03. Our records show this well was a gas injector (as of 8/31/03). I do not have a record of any notice from BP regarding a failed MIT/indication of communication as required by regulations. What is the current status of the well? Please note that longstanding AOGCC policy is no continued gas injection when there has been an indication of pressure communication or leakage; approval must be obtained (via sundry application) to continue operating the well with water only. Please advise. Jim Regg 1 of 2 10/3/2003 10:47 AM RE: Endicott Monthly Injection Report It should be included "Millholland, Madelyn A" wrote: Enclosed is the Endicott Monthly Injection Report for the wells on waiver. If you have any questions concerning this report, please feel free to contact me at the number shown below. <<03-Sep AOGCC Endicott Inj Report.xls>> Madelyn Millholland P,O. Box 196612 900 E. Benson Blvd. Anchorage, AK 99519-6812 ACT!- bata Phone: 907.564,5234 Fax: 907.564-4441 Interoffice, Mail: MB 4-2 Anchorage, AK en'lail ' millhoma@bp.com 2 of 2 10/3/2003 10:47 AN MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner P.I. rvisor FROM: Lou Grimaldi Petroleum Inspector DATE: September 13, 2003 SUBJECT: Mechanical Integrity Tests BPX Endicott, MPI 2-22, 1-69, 1-67 Duck Island Unit Endicott Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. We,,1 2-22/L-14 IT~,pe,r,j.I WAG I T.V.D.I~"~" I Tubingl 1200I~00 I 2450 I 2450 Ilntervall V I P.T.D.I 189-034I 'Typetestl P I TestpsiI 2369 ICasingI 1200I 2500I 2460I 2450I P/F IB Notes: Combo nMIT, plug set in T.T. @ 10,999' w~,,I ~-69/v-~9 ITY,~,ni.I wAe I T.V.D. 19249 I T,~,~I ~0 I~00 1~30 I~0 I,.,~,1 P.T.D.I 190-029ITypetestl P ITestpsil 2312 I Casingl 2450 I 2450 I 2450 I 2450I P/FI P Notes: Observed pretest conditions for 30 minutes "OK". w~,,I ~-~-~0 I T~,~,,i.I ~ I T.V.~. 19~ ]Tubingl ~0 I~00 1~3~0 I~0 I,nterva, I P.T.D.I 189-114ITypetestl WAG ITestpsiI 2314 ICasingI 3375I 3360I 3350I 3350 Notes: Observed pretest conditions for 30 minutes I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R- Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details 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 off prior 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. ~OANNED OCT .1. ,.&. 2003 2003-0913_M IT_D I U_2-22_lg .xls 9/15/2 OO3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich THRU: FROM: Commissioner DATE: September 19, 2003 %,, %/~./~--~ SUBJECT: Mechanical Integrity Test Jim Regg BPX P.I. Supervisor Endicott MPI DIU Chuck Scheve Endicott Field Petroleum Inspector NON- CONFIDENTIAl_ Packer Depth Pretest Initial 15 Min. 30 Min. w~,,J~-67rr-2o I Type,,j.I GI T.V.~. I~ I Tubi,gl~oo I~o0 I~00 I~00I Interval] 4 P.T,D.I 189-114ITypetestl P I Testpsil 2314 I CasingI 4O0 1245O1229O12140I P/F I _F Notes: third attempted pressure test. 14.5 bbls pumped during tests w~,,12-16,M-1~IT~,~J.I, s I T.V.D. 19~ I T~,~ I 1,,00 I~00 I~00 I1~00 I,~,~,l 4 P.T.D.I 188-134ITypetestl P ITestpsil 2343 I CasingI 1()00I 2500I 2480I 2480I P/F I g Notes: pretest pressures obse~ed for 30 minutes OK w.,,I ~_~,~o I~,.,n~.I ~ I ~.~.D. I~0~ I~,,~1 ~00 I~00 I~oo I~00 I,,,~,1 ~ P.T.D.I 190-077ITypetestl P ITestpsil 1759 I CasingI 500 I 25001 25001 25001 P/F I g Notes: pretest pressures obse~ed for 30 minutes OK ' w~, I I~ "~. I I ~.~.~. I I ~,,~ I I I I I'''~' P'T'D'I ITypetestl ITestpsil I Casing l I I I I P/F Notes: Well~ P.T.D.] Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs DIU MPI and witnessed thc 4 year MIT on wells 1-67,2-16 and 2-64. Wells 2-16 and 2-64 passed thc pressure tests. Well 1-67 had failed an MIT witnessed by Lou Grimaldi on 9/13/03 during which 41 bbls had been pumped. During today's pressure testing 14.5 bbls were pumped in three attempts to pressure test. The above listed pressures, from the final attempt, show a steady pressure decline of 150 psi per 15 minute interval. M.I.T.'s performed: _3 Attachments: Number of Failures: Total Time during tests: 5 hours cc: Tom Maunder AOGCC MIT report form 5/12/00 L.G. 2003-0919_M IT_End ico~...M P 1_2-64_cs.xls 9/24/2003 STATE OF ALASKA ALAS~'~-.OIL AND GAS CONSERVATION COMMISS'~,I REPORT Gr" SUNDRY WELL OPErlATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well_ Perforate X Other__ 2. Name of Operator BP Ex/~loration (Alaska)/nc. 3. Address P. O. Box 196612, Anchorac/e, Alaska 99519-6612 4. Location of well at surface 2230' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 1143' SNL, 3352' WEL, Sec. 01, T11N, R16E At effective depth 1418'SNL, 3456' WEL, Sec. 01, T11N, R16E At total depth 1454' SNL, 3468' WEL, Sec. 01, T11N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.1 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-67/T-20 9. Permit number/approval number 89-114/399-193 10. APl number 50- 029-21985 11. Field/Pool Endicott Off Pool feet 12. Present well condition summary Total depth: measured true vertical 12150' feet 10614' BKB feet Plugs (measured) 4-1/2" XXN Plug @ 11645' Effective depth: measured true vertical 12050' feet 10521' BKB feet Junk (measured) 3-3/8" PERF GUN 25'LONG @ 11970' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 64' 30" Driven 103' 103' 2459' 13-3/8" 3577 c.f. Permafrost 2498' 2498' 10923' 9-5/8" 575 c.f. Class G 10962' 9536' 1730' 7" 643 c.f. Class G lo683'- 12142' 9297'-10551' measured 11444;11454'; 11463;11473"111488;11496'; 11500;11506' (open);11509'-11525'(squeezed); 11528'-11550'(open); 11605'-11638' (Sandplug); 11702; 11739' (Mechanically Isolated) true vertical (subsea) 9911~-992~~; 9928~-9937~ ;9951~-9958~; 9961~; 9969~-9984~ (~pen); 9986~-1~~~9~ (squeezed); 10057'-10087' (Sandplug); 10145'-10176' (Mechanically Isolated) Tubing (size, grade, and measured depth)4-1/2"12.6#L-80with4-1/2"tailpipeto10748' Packers and SSSV (type and measured depth) 9-5/8" packer at 10664'; 7" WD packer at 11655'; 4-1/2" SSSV at 1551' 13. Stimulation or cement squeeze summary Add Perforation (10/24/99) 14. Intervals treated (measured) 11444-11454; 11463-11473 (MD) .......,.~..~,, Treatment description including volumes used and final pressure see attached Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4248 0 1727 Subsequent to operation 4903 1578 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations .. X 16. Status of well classification as: Oil_ Gas Suspended Service W_~fp.r/nip. char 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~Ined ~ ~-~"?'~" ~,J<,.~"k. i Title Form 10-404 Rev 06/1 Date 11 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 10124199 WELL N°: 1-67 1 T-20 BP EXPLORATION REP: SERVICE COMPANY: Additional Perforations Peruzzi SWS, Boehme Summary: Made 1 gun runs with 2" Powerjet 2006 HMX 6.5 gram charges, 6 spf, 60 degrees phasing. Correlated to 10112/89 CBT. PERFORATION SUMMARY: GUN INTERVAL, MDBKB FEET SUBZONE 1 11463-11473 10 FIV 2 11444-11454 10 FIV DATE/TIME OPERATIONS SUMMARY 10/24 Well is flowing. 1200 MIRU SWS. Pre job operational and safety meeting. SI well. 1300 RIH gun 1. Correlate. Shoot 11463-11473 1515 Shoot 11444-11454 1730 Rig down go home. RECEIVED r',. ,/0 2 1999 Al~ka Oil & Gas Cons. Commission Anchorage ALASKA OIL AND ~i'~' E(~ERVATtON COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well ,, Change approved program , ~7_ ' rill i ,Ill, I,1 2. Name of Operator __.B~P,,,Exoloration (Alaska)/nc. . ....... 3. Address P. 0. Box 198612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2230' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 1143' SNL, 3352' WEL, Sec. 01, TI 1N, R16E At effective depth 1418' SNL, 3458' WEL, Sec. 01, T11N, FI16E At total depth 1454' SNL, 3468' EEL. Sec. 01, T11N, R 16E ~-Piese'~t well condition summary Total depth: measured true vertical 12150' 10614' BKB feet Effective depth: measured true vertical Operation Shutclewn Re-enter SUSl0ende~t well ~ Plugging ~ Time extension ,, Stimulate ~ Pull tubing ~ Variance Perf(~'ra[e x Other Type of Well: Developmenl[ ExplorAtory ~ StratlgrAphle ~ Service x., RECEIVED 1999 6. Datum elevation (DF or KB) KBE -- 55. 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-67/T-20 9. Permit number 89-114/398-32 i 0. APl number 50-029-21985 11. Field/Pool Endicott Oil Pool .... Alaska 0ii & ¢~as Cons C ' feet Plugs~~) 4-1/2" XXN Plug @ 11645' 12050' feet Junk (measured) 10521'8KB feet feet ORIGINAL 25'LONG @ 11970' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured d~pjb True vertical depth BKB 64' 30~ Driven 103' 103' 2459' 13-3/8" 3577 c.f. Permafrost 2498' 2498' 10923' 9-5/8" 575 c.f. Class G 10982' 9536' 1730' 7" 643 c.f. Class G 10~83'. 1214F 9297'-10551' measured 11444,- 114&4~ 11463; 1147~, (s~ueeA,~) 1 f488'.f f43~,, f 1500~. f 1506' (open);~ f5o9'. 11525' (aqueezed): f 15E~'-1155o' (open); 1 leO5'-11E,38' ($anelplug); 117~'-1173~' (M#~ll~nt~ally ISOlated) true vertical r~u~ea) ~1 i,,9~20'; 992Eqg~37' (~queaze~) 9ggl'-,ggE8': 9861'; gsga'-9984' (oi~an); 9g~6'-lOOAg' (aquaazacl): 10057'-100~7' ($anCipl~g): 10 f45'. 10 f 7~' (MectlanJc, ally Isolated) Tubing (size, grado, and moaoured dopth} 4.1/2,12.6# L.80 with 4.1/2, taiipipe to10748, O I I NA L Packers and SSSV (type and measured depth) 9.5/8" packer at 10864'; 7" WD pacl(er at 11655'; 4-1/2" SSSV at 1551' 'ci~3. AttaChments " Description summary of proposal X Detailed operations program .~ BOP sketch X Estimated date'~r ~;~m~ncJng operation October2, 1999 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas. Service _W_a_te[.!.pjector Suspended__ 17. I hereby certi_f_,v that~the foregoing is true and~,correct to the best of my knowledge. Signed _~'~~~ Title ,~"'~z,,~,~/'~ ~ Date 9/29/99 FOR COMMISSION USE ONLY (~0nditions 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 2,/1;' ' d Location clearance __ I Approval N o.,.~ ~,./~'~ _ Subsequent form required 1~--~~ ORIGINAL SIGNED BY RobeA N. Christenson ~ ~ ~missioner Date SUBMIT IN TRIPLICATE Endicott Production Well 1-67/T~20 Additional PerforatingPro_gram Synopsis Objective Provide WAQ injection in Flow Unit iv in this part of the field. Justification Tkis well formerly produced fro~a all of the Upper Subzones except Fy. When it was converted to a WA(} injector in March 1999, which involved abandoning Fi & Fii, only the Fiii sands were reperforated at that time. Flow Unit iv now needs to be reperforated, while the well is on water injection, prior to its first MI cycle. Summary Procedure !. RIH with slickline and pull MCX sub-surface safety valve. 2, Drift to PBTD 3. Leave well shut-in for 7 days, then nm Kinley caliper and static pressure surveys, 4, Perforate the following intervals: Zone Top Bottom Length Gun Type Shot Density Fiv 11444' 11454' 10' 2" PowerJet 6 s.p.f. Fiv '1 t463' 11473' 10' 2" Power Jet 6 spt reference log: Schlumberger CBT dated 10 Dec 1989 5. Re-run MCX SSSV 6. Remm well to water injection on a fully open choke. Phasinq Orientation 60° random 60° random ORIGINAL cgs 9/29/1999 Z/C;'d dA":IC[ i103IOH3 Xd~ Ndl;q:gO 66, 6~ ~l-It::J BPA moco _ .. Fax Message BP Exploration (Alaska) Inc. P,O. Box 196612 MB3-6 900 E, Benson Boulevard Anchorage Alaska 99519-6612 Switchboard: (907) 561-5111 Central Fax: (907) 364-5200 From: Team: Subject: Madelyn Millholland (email: millhorna~bp.com) ENS/Endicott Application for Sundry Approvals URGENT _XX_ ORDINARY CONFIDENTIAL To: Blair Wondzell Copy tO: Company: AOGCC Team: Fax no: 276.7542 Date: September 30, lgg9 Direct Fax: (g07) 564.5200 Direct Tel: (907) 564-5200 Pages to follow: 6 pages Message: Mr, Wondzell: Enclosed are three Applications for Sundry Approval: an extension to waiver 398-285 for Injector 2-34/P-14; perforations for Injector 1-67/T-20; and perforations for Injector for 3- 49A/M-40. We wish to have at least verbal approval by this Friday, October 1, as it is possible may perforate the wells over the weekend. Please call me (563-5234) or Graham Stewart (563-5853) if you have any questions. Sincerely, Madelyn Millholland Technical Assistant 2./'1; 'd dA](] iiODIC[H':I Xd~[ Wd6t~: ~0 66, .6~ ,5)FLU ~ I ^ I i- UI- ALA~I&A A ~L~,%,A OIL AND GAS CONSERVATION COMMI~'":©N REPORT SUNDRY WELL OF.-'RATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging~ Pull tubing__ Alter casing __ Repair well Perforate_x_ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchoraqe, Alaska 99519-6612 4. Location of well at surface 2230' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 1143' SNL, 3352' WEL, Sec. 01, T11N, IR 16E At effective depth 1418'SNL, 3456' WEL, Sec. 01, T11N, IR16E At total depth 1454' SNL, 3468' WEL, Sec. 01, T11N, IR16E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service .. 6. Datum elevation (DF or KB) KBE : 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-67/7-20 9. Permit number/approval number 89-114/398-32 10. APl number 50- 029-21985 11. Field/Pool Endicott 0il Pool 12. Present well condition summary Total depth: measured true vertical 12150' feet 10614' BKB feet Plugs (measured) 4-1/2" XXN Plug @ 11645' Effective depth: measured true vertical 12050' feet 10521' BKB feet Junk (measured) 3-3/8" PERF GUN 25'LONG @ 11970' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 64' 30" Driven 103' 103' 2459' 13-3/8" 3577 c.f. Permafrost 2498' 2498' 10923' 9-5/8" 575 c.f. Class G 10962' 9536' 1730' 7" 643 c.f. C/ass G lO683'- 12142' 9297'-10551' ,, measured 11444'-11454'; 11463'-11473'(squeezed) 11488'-11496'; 11500'-11506'(open);11509'-11525'(squeezed); 11528'-11550'(open); 11605'-11638' (Sandplug); 11702'-11739' (Mechanically Isolated) true vertical (subsea) 9911'-9920'; 9928'-9937' (squeezed) 9951'-9958'; 9961'; 9969'-9984' (open); 9986'-10009' (squeezed); 10057'-10087' (Sandplug); 10145'- 10176' (Mechanically Isolated) Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 with 4-1/2" tailpipe to 10748' Packers and SSSV (type and measured depth) 9-5/8"packer at 10664'; 7" WD packer at 11655'; 4-1/2" SSSV at 1551' 13. Stimulation or cement squeeze summary Add Perforation Intervals treated (measured) 11540'-11550' MD Treatment description including volumes used and final pressure see attached ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 654 10698 12425 0 n/a 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended RECEIVE[ Alaska Oil & Gas Cons. corem Tubing p~ge 5o7 Service W~tp.r Ini. Rctnr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed I ~¢~'~ ~;J/~ ¢ ~( ~6~ "' t '~°O ~/~ (~'(~1 Form 10-404 Rev ~6/~5/~ SUBMIT IN DUPLICA BPX Endicott Production Engineering Department DATE: 4~27, 30~99 WELL N°: 1-67/T-20 BP EXPLORATION REP: SERVICE COMPANY: Additional Perforations D. Robe~son SWS DATE/TIME OPERATIONS SUMMARY 4/27/99 0800 1600 4/30/99 0800 1400 MIRU SWS. SIWHP = 1000 psig, lAP = 800 psig, CAP = 0 psig. Pre job operational and safety meeting. RIH with 10', 2 7/8" perf gun. Appeared TD was at 10,544 MDBKB immediately prior to tool failure. POH. RIH with second toolstring. Confirm TD at 10,544 MDBKB, 6' above bottom proposed perf. POH. CCH. RD. RU SWS. SIWHP= 820 psi, lAP= 820 psi, CAP = 0 psi. Pre job operational and safety meeting. Grease swab. RIH with 10', 2 7/8" gun, gr/ccl. Tie in with 12/10/89 SWS CBT. Sat down very gently initially at 11,548 MDBKB due to stickiness .observed while bailing. Able to work gun down to 11,551 MDBKB on subsequent attempts at higher speed. No overpull coming off bottom. Made several passes to confirm depth control. Perforate 11,540-11,550 MDBKB. SIWHP=820 psi immediately prior to perforating and after rig down. Log off and POH. CCH. RD. PERFORATION SUMMARY: GUN INTERVAL, MDBKB 1 11,540-11,550 FEET SUBZONE 10 Fill Gun type: SWS 2 7~8" HSD, 6 spf, 20.57" penetration, EHD=0.29", 34J UJ charges, 60 deg phasing, random orientation RECEIVED 1 '7 199.q. Anchorage STATE Of ALASKA ALA?-~'-OIL AND GAS CONSERVATION COMMISF~''' I REPORT L,r: SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate Plugging X Perforate__ Pull tubing__ Alter casing __ Repair well__ Other × 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchora.~e, Alaska 99519-6612 4. Location of well at surface 2230' SNL, 2224' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service .. 6. Datum elevation (DF or KB) KBE = 55.1 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-67/T-20 feet At top of productive interval 1143' SNL, 3352' WEL, Sec. 01, T11N, R 16E At effective depth 1418'SNL, 3456' WEL, Sec. 01, T11N, R16E At total depth 1454' SNL, 3468' WEL, Sec. 01, T11N, R16E 9. Permit number/approval number 89-114/398-32 10. APl number 50- 029-21985 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: 12150' feet Plugs (measured) true vertical 10614' BKB feet measured 12050' feet Junk (measured) true vertical 10521' BKB feet Length Size Cemented 4-1/2" XXN Plug @ 11645' 3-3/8" PERF GUN, 25'LONG @ 11970' Measured depth True vertical depth BKB BKB 64' 30" Driven 103' 103' 2459' 13-3/8" 3577 c.f. Permafrost 2498' 2498' 10923' 9-5/8" 575 c.f. Class G 10962' 9536' 1730' 7" 643 c.f. Class G 10683'- 12142' 9297'-10551' measured 11444'-11454'; 11463'-11473? 11488'-11496'; 11499'-11506'; 11509'-11525'; 11527'-11552'(AIlOpen) 11605'-11638'(Sandplug); 11702'-11739' (Mechanically Isolated) true vertical (subsea) 9911'-99207 9928'-9937'; 9951;99587 99617 9970;9984? 9986;10009' (All open); 10057'-10087' (Sandplug); 10145'-10176' (Mechanically Isolated) Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 with 4-1/2" tailpipe to 10748' Packe rs and SSSV (type and measu red depth) 9-5/8" packer at 10664'; 7" WD packer at 11655'; 4-1/2" SSSV at 1551' 13. Stimulation or cement squeeze summary NRWO Sand Plug and Cement Cap in preparation for conversion to water injector Intervals treated (measured) 11,575'-11,659' Treatment description including volumes used and final pressure see attached 0RI$1NAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 654 10698 12425 0 n/a Tubing Pressure 507 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations × 16. Status of well classification as: Oil × Gas__ Suspended__ Service W~fp.r In?,~.f,'~r 17. I hereb, y...certify that the foregoing is true and correct to the best of my knowledge. Signed( '~\ '~'~~, ~'"%v~,~~_~ Title ~eoinr T~hni~l A.~.~i.~t~nt IV r,_,_. ' ~UBMIT IN DUPLICATE~ i Form 10-404 Rev 06/15/~1 .~R4.~:~.':14 Date 4/14/99 To: G. Stewart From: Kirby Walker Operation: Endicott 1-67 Job Id: Sand Plug w/ Cement Cap · ..,cation: Anchorage Cost Code: Detail Code: N10 167 NRWO / Sand Plug / etc Summary MIRU Dowell #2. Pump ball through new coil string. RU to well and pump down annulus to kill. RIH with BHA #1 and tag bottom. Adjust depth to recent S/L tag of 11,659' and mix gel for sand plug. Pump and displace sand slurry. Tag top of sand at 11,603'. Wait on water. Re-tag while mixing cement and find top of sand at 11,600'. Mix and pump cement with a fresh water spacer and foam pigs ahead and behind cement. Drop ball with second pig to shear nozzle. Lay in cement leaving TOC at 11,575', pull to expected TOC and shear pins. POOH freeze protecting coil. A total of 14 BBL of methanol was pumped down the tubing. Due to insufficient volume of freeze protect, 5 bbl of void space was left underbalancing the well by-130 psi. 03/29/99 Initial Well Status Fwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F SI 2270 300 200 N/A 0 135 Time Operation 07:00 MIRU Dowell #2, 17,100' of 1-3/4" (ctv 37.0 bbls). Wait on 2" valves to be brought from WOA and water from Hot Water Plant at ARCO. 13:30 Pressure test surface lines to 4,000 psi. 13:45 Hold safety meeting. Spill champion - Scott Kiser. 14:25 Pump 7/8" ball through coil on new string. Shear nozzle. 15:10 RO well, re-pin nozzle. 16:10 RU on well and begin to kill well. 17:00 Start in hole. 3~30 20:00 Start pumping sand plug. 21:20 Tag top of sand. Wait on fresh water. (Hot Water Plant having problems.) 00:10 Start mixing cement. 01:00 Place cement, POOH. 02:45 On surface with coil. RDMO coil. Time Depth Rate Ctp Whp Total Remarks ft bpm psi psi bbls 16:10 0 4.5 2191 2305 42 Start pumping down annulus to kill well. 16:58 0 1.0 3000 775 218 Start in hole. FP surface lines (5 bbls), pump down coil. 18:05 5400 1.0 1885 840 282 Pickup- 10,350#. 18:50 10560 1.0 2085 852 332 Pick up - 20,500#. 19:04 11547 0.0 770 795 342 See bobble as we pass through cement sheath. 19:06 11646 0.0 780 795 344 Tag bottom. Adjust counters (12' deep). Operation: Endicott 1-67 Page: 2 20:00 11659 1.0 4000 975 2 Mix sand. Pressure test lines. Pump gel ahead. 20:08 11659 1.5 2537 980 6 Start sand. 20:16 11659 1.4 2580 1000 3 Start gel behind. 20:18 11659 1.5 2535 1010 Start displacement. 20:36 11659 1.5 2710 1190 30 Proppant at nozzle. 20:37 11659 1.5 1640 1360 31 POOH layin9 in proppant. 20:45 11000 0.0 990 1100 32 Park coil and allow sand to fall. 21:22 11603 0.0 820 1000 Ta9 top of sand. Wait on water. 23:45 Water an'ives. Start mixing cement. 23:58 11600 Dry tag sand top. 3/30 00:10 11595 0.0 145 1015 Start mixing cement. Load first plug into coil. 00:20 11595 1.5 690 910 2 Start water ahead. 00:22 11595 1.5 680 910 1 Start cement. 00:30 11595 1.5 685 900 20 Drop second plug and ball. Start fresh water behind. Taking returns down flowline of 1-61. 00:48 11525 1.5 2100 1000 12 Switch to methanol and continue displacement keeping back pressure. 01:00 11595 1.0 1435 975 16 Lower rate. 01:02 11595 0.5 1210 950 17 Cement at nozzle. 01:03 11595 0.0 1500 700 17 PUH to above expected TOC and shear pins. POOH. 01:58 5000 1.0 37 Complete FP of coil. Pump down annulus to FP tubing. 02:42 0 0.0 610 725 49 On surface with coil. RDMO Dowell. Final Well Status Fwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F SI 725 480 0 N/A 0 120 Fluid Summary 344 Seawater. 344 11 Gel 11 1 Cement 1 22 Fresh water 2 + 20 96 Meoh. 42+5+49 474 Total 1300 20/40 CarboLite Jet Swirl Nozzle Bottom Hole Assembly # 1 Tool Stdng Descriptions O.D. I.D. Length Comments DS ct connector. 2.00 1.00 0.125 DS Stinger. 2.00 1.00 5.75 Ball drop nozzle. 2.75 - 1.58 7/8" ball, 6 up-jets when sheared Total Length 7.455 DS Cement Summary Operation: Endicott 1-67 15.8 PPG Class G Cement containing: 0.020 gps D047 0.53 % BWOC D156 0.20 %BWOC D065 0.22 % BWOC DS00 Thickening Time = 4 hrs and 00 mins. Lab APl fluid Loss = 94.0 mi @ 170 Deg. F. Requested 3-5 hours Page: 3 BP EXPLORATION November 19, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. B. Wondzell Dear Mr. Wondzell, Please find the attached application for Sundry Approval for Endicott SDI injection well 1-67/T- 20. This well was initially drilled as a SDI producer for the upper subzones, but since November, 1997 the well has not been economical to produce because of high water production. Due to its optimal position for establishing a miscible injectant (MI) flood in Subzone Fiii, well 1-67/T-20 has been selected for conversion into an EOR injector. BP requests approval to convert this well into an EOR injector with alternating water and MI injection service. Please do not hesitate to contact me at 564-5952 or Graham Stewart at 564-5853 if you require additional information regarding the proposed course of action on well 1-67/T-20. Sincerely, Scott R. McEntyre Endicott Development Group MPI Production Engineer attachments (2) SI'II1 ec: 1-67/T-20 Well File / AOGCC File 06.10 Stewart, G. Endicott Wells Team Leader STATE OF ALASKA ALAS~''~. OIL AND GAS CONSERVATION COMMIS: q APPLICA'I,ON 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 __ Other x 2. Name of Operator BP Ex/~loration (Alaska)/nc. 3. Address P. O. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 2230' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 1143' SNL, 3352' WEL, Sec. 01, T11N, R16E At effective depth 1418' SNL, 3456' WEL, Sec. 01, T11N, R16E At total depth 1454' SNL, 3468' WEL, Sec. 01, T11N, R16E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service x 6. Datum elevation (DF or KB) KBE = 55.1 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-67/T-20 9. Permit number 89-114 10. APl number 50 - 029-21985 11. Field/Pool Endicott Oil Pool feet 12. Present well condition summary Total depth: measured true vertical EffectiVe depth: measured true vertical 12150' feet 10614' BKB feet 12050' feet 10521' BKB feet Plugs (measured) 4-1/2"XXN Plug @ 11645' 25'LONG @ 11970' Casing Length Size Cemented Measured d~ True vertical depth Structural BKB Conductor 64' 30" Driven 103' 103' Surface 2459' 13-3/8" 3577 c.f. Permafrost 2498' 2498' Intermediate 10923' 9-5/8" 575 c.f. Class G 10962' 9536' Production ~z i4 z- ~,~¢- ,l~o& ~o55-j iz[~]~ Liner 1730' 7" 643 c.f. Class G 10683'- 1~' 9297'-~ Pedoration depth: measured 11444'- 11454', 11463'- 11473', 11499'- 11500? 11540511552? 11605'- 11638? ¢flsqueeze¢ 11488511496? 11500511506? 11510511524? 11528511540'' 11702'- 11736'(open) ~ , ; ' ~ _¢,~ ,, true ve~ical Cubsea) 9911L 9920', 99285 9937? 9961L 9962'; 99985 10009? 10057L 10087' Cfi squeeze¢ 9951L 9958: 9962L9967'; 9971'9984'; 9987L9998'; 10145'-10176' ¢Pe¢ NOV 2 7 ~'398 Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 with 4-1/2" tailpipe to 10748' Packers and SSSV (type and measured depth) 9-5/8" packer at 10664'; 7" WD packer at 11655'; 4-1/2" SSSV at 1551' 13. Attachments Description summary of proposal X Detailed operations program Request to convert from producin.cl well to iniection service weft attached. BOP sketch X 14. Estimated date for commencing operation January, 1999 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas__ Suspended__ Service Water 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~o''~r' ~. /~¢~/-/~ Title g,'~lc'~r'/'~ ~L4. PI Date 11/19/98 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test ¢ Approved by order of the Commission Form 10-403 Rev 06/15/88 I Approval N°.,~/4;' ~-' ~2., / Subsequent form required 10-~ 0ricjii~l Sigp,~.d By ,.r,.¢6 David W, Johnston ~,9°' 9'e~.~'/~~Commissioner SUBMIT IN TRIPLICATE AI~..ICATION FOR SUNDRY APPRO'v ENDICOTT POOL WELL 1-67/T-20 November 19, 1998 Background Well 1-67/T-20 has historically produced from Fiv, Fiii, Fii, and Fi subzones, with subzone Fiii contributing the majority of the total production. Cummulative production from this well is approximately 3 MMSTB. All opportunities to sustain competitive production from this well have been attempted, and it has been determined that this well's maximum remaining value is as an EOR injector. Well 1-67/T-20 has demonstrated communication with upper subzone water injectors 1-69/V-19 and 4-04/T-26 via tracer sampling. Nearby producers 1-55/R-25, 1-57/R-23, and 1-63/T-22 also display connectivity to water injection support from 4-04/T-26 as demonstrated by tracer sampling data. This common connectivity indicates these well's strong potential as EOR offtake producers. Overall, MI injection into well 1-67/T-20 coupled with MI injection into well 4-04/T- 26 will establish an optimal flood pattern to maximize the EOR benefits from this area of the reservoir. This well demonstrated pressure integrity by passing a standard MIT on 8/22/98. A cement bond log obtained on 12/10/89 indicated satisfactory cement competence between subzones of the reservoir and approximately 100' of competent cement above the top perforation interval. The tubing is believed to be in good condition, based on a series of Kinley Caliper Surveys run in 1993 and 1994. These surveys showed the tubing to be mostly in "fair" condition, with only a small increase in corrosion observed in the year between the surveys. Since the well has been shut-in for approximately 24 of the past 54 months, the tubing is not expected to be significantly more corroded than when last measured in 1994. Recommendation Because well 1-67/T-20 is no longer able to produce competitively, its maximum remaining usefulness is as an EOR injector. This well is favored for EOR injection based on its location and calculations showing the well can maintain integrity while injecting MI and water. Precautions will be taken when the well is initially placed on production to ensure that its mechanical integrity remains intact. BP Exploration believes the well can serve as an effective EOR injector without compromising safety or the environment. Your permission for conversion to injection is requested. STATE OF ALASKA .._, AI_~'~-"OIL AND GAS CONSERVATION COMMI? I REPORT SUNDRY WELL OF,.RATIONS Rrc C. I: I v [: :, 1. Operations performed: Operation shutdown __ Pull tubing__ Stimulate __ Plugging Alter casing __ Repair well __ Perforate__ ~laska 0i~ & Gas B0ns, BO Other X ;' 6. Datum elevation (DF or KI~ 2. Name of Operator BP Ex/~loration (Alaska)/nc. 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at surface 2230' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 1143' SNL, 3352' WEL, Sec. 01, T11N, R 16E At effective depth 1418' SNL, 3456' WEL, Sec. 01, T11N, R16E At total depth 1454' SNL, 3468' WEL, Sec. 01, T11N, R16E 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service KBE = 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-67/T-20 9. Permit number/approval number 89-114iNet Reouired 10. APl number 50- 029-21985 11. Field/Pool Endicott Oil 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: 12150' feet 10614' BKB feet 12050' feet 10521' BKB feet Plugs (measured) Junk (measured) Length Size Cemented 4-1/2" XXN Plug @ 11645' 3-3/8" PERF GUN L /t 25'LONG @ 11970' Measured depth True vertical depth BKB BKB 64' 30" Driven 103' 2459' 13-3/8' 3577 c.f. Permafrost 2498' 10923' 9-5/8" 575 c.f. Class G 10962' 1730' 7" 643 c.f. Class G 10683'- 12413' measured 11444'- 11454', 11463'- 11473', 11499'- 11500~ 11540'-11552~ 11605'- 11638~ (allsqueezed) 11488'-11496'; 11500'-11506'; 11510'-11524~ 11528'-11540'; 11702'- 11736'(open) true vertical (subsea) 9911'-9920', 9928'-9937'; 9961'-9962~ 9998'- 10009'; 10057'-10087' (AII squeezed) 9951 '- 9958'; 9962'-9967'; 9971 '-9984'; 9987'-9998'; 10145' - 10176' (open) Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 with 4-1/2" tailpipe to 10748' 103' 2498' 9536' 9297~10858 Packers and SSSV (type and measured depth) 9-5/8" packer at 10664'; 7" WDpackerat 11655'; 4-1/2" SSSVat 1551' 13. Stimulation or cement squeeze summary ~ L I V L lJ Intervals treated (measured) 14. Treatment description including volumes used and final pressure MIT (8/22/98) Alaska 0ii & Gas Cons. Commission Anr, hnrage Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 654 10698 12425 0 507 Subsequentto operation n/a 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil x Gas__ Suspended Service S17' I herebycertifythatthe foregoing is true and correct tothe best of my knowledge.~/!~ ~ i~l ~ [ Date 09/02/97 igned ~/~f, · (.¢-~¢~_~' Title Senior T~_hnin~l A.~.ei.et~nt IV T~t_ .';~;,~..';P.~,~ Form 10-404 Rev 0 /88' 15 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 8~22~98 WELL N°: 1-67/T-20 BP EXPLORATION REP: Varble SERVICE COMPANY: HB&R (Ron W.) Fluid Pack & Test IA DATE/TIME O93O 1030 1047 1048 1050 1103 1108 1127 1159 1224 OPERATIONS SUMMARY Load 80 bbls diesel MIRU HB&R SIP = 1950 lAP = 450 OAP =125 P/T hardline to 3000 ps~. Start pumping diesel down IA @ I bpm, 450 psL Increase rate to 4.3 bpm @ 600 ps~ 60 bbls away, 4.3 bpm, 900 ps~ 80 bbls away, 2500 psi. Shut down pump. Pressure fell off to 2150 psi. Bump up to 2500 psL Holding 2500 psi for 30 min. Good test. Bleed lAP down to 500 ps~. RDMO SIP = 1950 lAP = 500 OAP = 125 SUMMARY: Pumped a total of 82 bbls diesel and P/T IA to 2500 psi for 30 minutes. Passed MIT. Bled lAP down to 500 psi. _~___~- Note: lAP WILL NEED TO BE CLOSELY WATCHED WHEN WELL IS PUT ON INJECTION DUE TO THERMAL EXPANSION. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate~ Plugging Pull tubing m Alter casing m Repair well __ 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 2230' SNL, 2224' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development ,,. Exploratory ~ Stratigraphic ~ Service ~ 6. Datum elevation (DF or KB) KBE = 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-67/T-20 At top of productive interval 1143' SNL, 3352' WEL, Sec. 01, T11N, R16E At effective depth 1418' SNL, 3456' WEL, Sec. 01, T11N, R16E At total depth 1454' SNL, 3468' WEL, Sec. 01, T11N, R16E 9. Permit number/approval number 89-114~Not Required 10. APl number 50- 029-21985 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 12150' feet 10614' BKB feet Plugs (measured) 4-1/2" XXN Plug @ 11645' Effective depth: measured true vertical 12050' feet 10521' BKB feet Junk (measured) 3-3/8" PERF GUN 25'LONG @ 11970' Casing Length Structural Conductor 64' Surface 2459' Intermediate 10923' Production Liner 1730' Perforation depth: Tubing (size, grade, and measured depth) Size 30" 13-3/8" 9-5/8" Cemented Measured depth True vertical depth BKB BKB Driven 103' 103' 3577 c.f. Permafrost 2498' 2498' 575 c.f. Class G 10962' 9536' 7" 643 c.f. Class G 10683'- 12413' 9297'- 10858 measured 11444'- 11454', 11463'- 11473', 11488'- 11496'; 11499'- 11506'; 11540'-11552'; 11605'- 11638'; (all squeezed) 11510'-11524'; 11528'-11540'; I 1702'- 11736'(open) true vertical (subsea) 9911; 9920', 9928; 9937'; 9951; 9958'; 9961; 9967'; 9998'- 10009'; 10057'-10087' (All squeezed) 9971'-9984': 9987;9998': 10145' - 10176' 4-1/2" 12.6# L-80 with 4-1/2" tailpipe to 10748' Packers and SSSV (type and measured depth) 9-5/8" packerat10664~ 7" WD packerat11 13. Stimulation or cement squeeze summary Intervals treated (measured) ORIGINAL Treatment description including volumes used and final pressure 0 1997' Amain 0it & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 25 174 4889 0 387 3591 6920 0 Tubing Pressure 283 9O6 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended__ Service 17. I hemb¥~certify that the fqregoing is true and correct to the best of my knowledge. , ;,/ Y Signe~t,.~ ....... ~ Title Senior Technical Assistant IV Form 10-4~../Rev 06/1,~/88C/ ' ' · '/ Date 12/30/96 SUBMIT IN DUPLICATE Endicott Production Engineering Department Add-Perfs D AT E: 10/28/96 WELL N°-: 1-67 / T-20 BP EXPLORATION REP: R. Clump SERVICE COMPANY: SOS (John Majcher / Carlo A. Yon) DATE/TIME OPERATIONS SUMMARY 10/28 1430 SOS Miru. Sniff well house prior to entry (310 ppm H2S). Sip= 1000 psi. 1630 Call for radio silence. Place perforating signs around MPI. 1715 Rih w/3-3/8"x 12' RDX deep penetrating guns @ 4 SPF, 60/120° phasing. Total string length 32.5'. Distance from MP to TS= 12.5'. 1830 Log tie-in pass from 11550' to 11380'. Tied into SOS CBL dated 12/10/89 (+20'). Log into place @ CCL depth of 11515.5'. 1850 Shoot gun from 11528-11540' md bkb. No good indications. Try to log off, we are stuck. Work free and Pooh. 2000 OOH. SIP= 1000 psi. RDMO SOS. POP FOC w/1 mmscf lift gas. 1 0/29 Increase lift gas to 2.6 mmscf. PERFORTION SUMMARY' GUN DEPTH LENGTH ZONE I 11528'-11540' 12' Fiii (3Cl) Interval was shot w/ 3-3/8" RDX, 4 spf, 60/120° phasing, & random orientation. JAN 02 1997 Alaska 0ii 8, Gas Cons. Commission Anch0r~e Endicott Production Engineering Department Add-Perfs DATE: 12/6/96 WELL N-°: 1-67 / T-20 BP EXPLORATION REP: SERVICE COMPANY: D Varble SOS (John Majcher) DATE/TIME OPERATIONS SUMMARY 1230 MIRU SOS. Sniff wellhouse FWHP=350 IA=1900 OA=400 1330 Wire backlashed on reel. Shut down to fix wire. 1530 Hold saftey meeting. Call for radio silence & arm gun 1610 SI well & RIH with gun 1~730 Out of TT. Open choke to 55 beans to under balance well. 1755 Log tie in pass. Tie into CET dated 12/10/89: Add 20' 1815 On depth. Hang cci @ 11499.5' (10.5' from cci to top shot) 1825 Shoot gun from 11510'- 11524' MD. No indication that gun fired. 1830 Log off. Pooh 1940 Ooh 2005 Confirm ali shots fired. 213O RDMO PERFORTION SUMMARY- GUN DEPTH LENGTH ZONE I 11510'-11524' 14' Fiii (3Cl) Interval was shot w/ 3-3/8" RDX, 4 spf, 60/120° phasing, & random orientation. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Perforate Pull tubing__ Alter casing __ Repair well __ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development .. Exploratory Stratigraphic __ Service __ 4. Location of well at surface 2230' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 1143'SNL, 3352' WEL, Sec. 01, T11N, R16E At effective depth 1418' SNL, 3456' WEL, Sec. 01, T11N, R16E At total depth 1454' SNL, 3468' WEL, Sec. 01, T11N, R16E ORIGINAL 6. Datum elevation (DF or KB) KBE = 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-67/T-20 9. Permit numbedapproval number 89-114~Not Required 10. APl number 50- 029-21985 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 12150' feet 10614' BKB feet Plugs (measured) Effective depth: measured true vertical 12050' feet 10521' BKB feet Junk (measured) 3-3/8" PERF GUN 25'LONG @ 11970' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 64' 30" Driven 103' 103' 2459' 13-3/8" 3577 c.f. Permafrost 2498' 2498' 10923' 9-5/8" 575 c.f. Class G 10962' 9536' Tubing (size, grade, and measured depth) 1730' 7" 643c. f. ClassG 10683'-~2413' ED measured 11444' - 11454', 11463' - 11473', 11488' - 11496'; 11499 - 11506'; 11509' - 11552';, 11605' - 11638'; (all squeezed) 11702'-11736' ,.AeUe~~ 1 2 1996 true vertical (subsea) 9911; 9920', 9928'- 9937', 9951'- 9958'; 9961'- 9967'; 9970'- 9984, vvvv'- 10009 ~. 10057'- 10087' (All squeezed) 10145'- 10176' Alaska 0il & {3as Cons. Commis 4-1/2" 12.6# L-80 with 4-1/2" tailpipe to 10748' Anchorage Packers and SSSV (type and measured depth) 9-5/8" packer at 10664'; 7" WD packer at 11655'; 4-1/2" SSSV at 1551' 13. StimulatiOn or cement squeeze summary Gas shut off squeezes (6-17-96) Intervals treated (measured) 11605'-11638' Treatment description including volumes used and final pressure Fresh sea water=l,022 bbls. Gel=9 bbls, Slurry=l.$ bbls, 25bbls 15% HCU10% XYLENE, Effluent water--28 bbls, Cement=18 bbls, sea water 74 bbls. FSlWHP-I§OOpsi 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 28 0 2494 0 25 0 4889 0 Tubing Pressure 284 283 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby/certify that. the fpre~oing is tru~ and correct to the best of my knowledge. Signed ~ /(~')/~,,~,~~ Title Senior Technical Assistant IV Form 10-404 ~ev 06/15/88 - ' - Date <~ I [7,71" ~ (,:~ SUBMIT IN DUPLICATE ;ion STATE OF ALASKA ALA,...,A OIL AND GAS CONSERVATION COMMISSI~,, REPORT OF SUNDRY WELL OPERATIONS 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. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2230' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 1143' SNL, 3352' WEL, Sec. 01, T11N, R16E At effective depth 1418' SNL, 3456' WEL, Sec. 01, T11N, R16E At total depth 1454' SNL, 3468' WEL, Sec. 01, T11N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service O I61NAL. 6. Datum elevation (DF or KB) KBE = 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-67/T-20 9. Permit number/approval number 89-114INet Required 10. APl number 50- 029-21985 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 12150' feet 10614' BKB feet 12050' feet 10521' BKB feet Plugs (measured) Junk (measured) Size Cemented Measured depth ~.~(;~i~cal depth BKB BKB 64' 30" Driven 103' 103' 2459' 13-3/8" 3577 c.f. Permafrost 2498' 2498' 10923' 9-5/8" 575 c.f. Class G 10962' 9536' 1730' 7" 643 c.f. Class G 10683'- 12413' 9297'-10858 Tubing (size, grade, and measured depth) measured 11444' - 11454', 11463' - 11473', 11488' - 11496'; 11499' - 11506'; 11509' - 11525'; 11527' - 11552? (afl squeezed) 11605'- 11638'; 11702'- 11736' true vertical (subsea) 9911; 9920', 9928'- 9937', 9951; 9958'; 9961'- 9967? 9970'- 9984'; 9986'- 10009'; (All squeezed) 10057'- 10087': 10145'- 10176' 4-1/2" 12.6# L-80 with 4-1/2" tailpipe to 10748' Packers and SSSV (type and measured depth) 9-5/8" packer at 10664? 7" WD packer at 11655'; 4-1/2" SSSV at 1551' 13. Stimulation or cement squeeze summary Gas shut off squeezes #1 (8/26/94), #2 (8/28/94) and #3 (8/30/95) Intervals treated (measured) 11444' - 11454', 11463' - 11473', 11488' - 11496'; 11499' - 11506'; 11509' - 115257 11527' - 115527 11605' - 11638'; 11702' - 11736' Treatment description including volumes used and final pressure See attachments. GSO #1 FSWHP = 2500 psia; GSO #2 FSWHP = 2500 psia and GSO #3 FSWHP = 1624 psia 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1178 11269 7883 0 28 0 2494 0 Tubing Pressure 1258 284 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is t~,e/nd correct to the best of my knowledge. Signed(~i'~-~~ C"~. ~ Title Senior Technical Assistant II Form 10,~4 Re~ 06/15/88 Date //.~/~x~ SUBMIT IN DUPLICATE ~.~ SUMMARY Bullhead killed the well with 290 bbls (1.5 wellbore volumes) filtered seawater. Noticed a pressure increase when the water hit the perfs, but pressure eventually stabilized at 1700 psi while pumping 5 bpm. Ordered Maraseal and ran in. Pumped at minimum rate while RIH for gas suppression. Tagged bottom at 11,572 CTD, and corrected to 11,552. Continued pumping at minimum rate while waiting on Maraseal. Static WHP was 524 psi, so reservoir pressure is 4924 psi. Pumped 116 bbl maraseal and displaced with seawater. Observed slow pressure rise once Maraseal hit the formation. Reduced rate when WHP reached 1800 psi. With 92 bbl in the formation, (96 out the nozzle), WHP was 2000+ psi at 0.25 bpm. Laid remainder of the Maraseal in the liner, and shut down to observe pressure. Pressure holding good. Pulled out of the well while pumping coil displacement. Left well shut in with 1600 psi to allow Maraseal to set up. FLUIDS PUMPED B BLS. DESCRIPTION 290 Bullhead kill with seawater 150 Pump min rate for gas suppression and increase rate for cooldwn 116 Maraseal 65 Displace maraseal and pump coil voidacje while POOH. BOTTOM-HOLE ASSEMBLY ..[ Tool Strin~l Descriptions I O.D. I I.D. I Length I Comments ., Coiled tubing connector 2.75 0.86' Petradat/barrier 3.0 2.8' set to record external pressures Crossover 2.75" 0.58' Check valves 2.25" 0.875' Nozzle 3.25" 0.23' bicj hole nozzle TOTAL 5.35' OPERATION: Circulation killed to minimize plugging. Partial returns @ 2.25 BPM. SIWHP=430. Did not pump below top perf so as not to stir up any CL, Did not cool sump. Bullheaded acid and cement from top perfs. Injectivity before acid was I BPM/460 psi. No improvement after. Ramped to 2000 initial squeeze pressure. Approx I bbl behind pipe. Cement locked up immediately indicating the leak was at the top perf. Quickly ramped to 3500. No additional cement behind pipe. 3500 PT bled 300 psi/10 min. Cycled down to 2000 and back up. No improvement. 2000 PT jug tight. Live cell showing 52. Began LRO. Final live cell of 81 cc as perfs are uncovered. LRO to 11557'. Recovered 13.5 bbls of cement. Lost 30 psi in 10 minutes. Drop ball and jet up to safety and down to TD. Lost 50 psi in 10 minutes. Final reverse out yielded no cmt. Reversed in 50 bbls SW displacement with nitrogen. Close swab and purge nitrogen out of coil with SW to slop tank. Left whp of 2500 psig. Leave well shut-in until 8/30/94 and then check inflow. FLU 542 0 4 40 10 14 19 21.1 245 100 78 50 IDS BBLS SW TO LOAD WELL BBLS SW TO COOL SUMP BBLS ACID BBLS SW (OVERFLUSH) BBLS FW (PREFLUSH) BBLS CEMENT BBLS FW (SPACER) BBLS BBLS BBLS BBLS BBLS SW (DISPLACEMENT) SW (LIVE REVERSE OUT) SW (JET PASS) SW (FINAL REVERSE OUT) RECOVERED (N2 DISPLACEMENT) 315 13.5 0 WELL CLEANED OUT TO 11557' BBLS LOAD FLUID BEHIND PIPE TODAY(^pPROX TOTAL IS 615 BBLS) BBLS CEMENT RECOVERED (DOES NOT INCLUDE CEMENT NOT PUMPED) BBLS CEMENT LEFT IN LINER ACID 15% HCL 0.4% NE-41 O.4% ACI-274 0 .7% S-500 I PPB FERROTROL 210 CEMENT 15.8 PPG CLASS "G" CMT CONTAINING 0.5% FL-33 0.1% CD-32 0.35% R-11 1.0 GAL PER SK FP-6L 0.1% S-400 THICK TIME = 7 HRS 22 MIN INCLUDING 1 HOUR SURFACE TIME LAB APl F.L. = 50 ML @ 170°F (REQUESTED RANGE 40 TO 55 ML) FIELD APl F.L. = 48 ML, F.C. = 3/4". PV=. YP=. LIVE F.L. = 81 ML, F.C. = OPERATION: Page ~O '~f'/ <'/-'~/~,/-z~//d~ 4 SUMMARy No injectivity loss noted during the initial bullhead kill. Inj was 4.5 BPM/650 psi. SIWHP--450. Estimated that BHP similar to 1-55 @ 4753 psi. Tagged XXN plug @ 11680' and corrected to 11666'. Layed in 20/40 CL to 11580' w/chokes cracked so as to attempt to avoid screening out the perfs. Very gassy. Attempted to rebullhead. Perfs plugged w/CL. Injectivity dropped to 3 BPM/2800 psi. Surged perfs and flowed the well. Attempted to tag CL plug. It was fluffed up from the inflowing. Injectivity improved to 2 BPM/1300 psi. Unable to flow the well due to the likelihood that the CL plug would flow back and due to solids handling constraints at the GC. Decided that the best course of action was to continue with the squeeze. Tagged CL plug @ 11578'. Surged the well one more time at 2600 psi and flowed for 10 min. Circulation killed holding 50 psi downstream choke pressure or at least 50 psi over SIWHP. Tagged CL plug @ 11578'. Cooled sump. Skipped acid to avoid pumping into perfs until cement was across them. Laid in 5 bbls cmt to cover perfs and increased WHP to 2000 while the total 17 bbls of cmt was laid in. Rapidly ramped WHP to 3500 psig. NO indications of any cmt behind pipe. Hold 3500 psig for only 20 minutes and LRO to 11566'. About 15 bbls cmt returned. No WHP drop for 10 minutes. Drop ball for jet pass. No pressure loss for 10 minutes. Make a final reverse out. Recover another 1.5 bbls cmt, for a total of 16.5 bbls leaving less than 1/2 bbl behind pipe. Final 10 minute pressure test lost no pressure. POOH and recover 50 bbls SW with reversing in nitrogen. Leave WHP of 2500 FLUIDS 2 0 8 BBLS SW BULLHEAD KILL #1 6 BBLS 40 PPT HEC GEL W/GBW-5 BREAKER 1 2 BBLS 40 PPT HEC GEL W/GBW-5 BREAKER AND 1725~ 20/40 CARBOLITE. 3 4 BBLS SW DISPLACEMENT 9 7 BBLS SW (PLUGGED PERF PROBLEM) 21 8 BBLS SW (CIRCULATION KILL) 1 9 4 BBLS SW TO COOL SUMP 1 0 BBLS FW (PREFLUSH) 1 8 BBLS CEMENT I 7 BBLS FW (SPACER) 2 2 BBLS SW (DISPLACEMENT) 2 3 4 BBLS SW (LIVE REVERSE OUT) 9 0 BBLS SW J ET PASS 5 6 BBLS SW (FINAL REVERSE OUT) 5 0 BBLS RECOVERED (N2 DISPLACEMENT) 300 16.5 MIN WELL CLEANED OUT TO 11566' BBLS LOAD FLUID BEHIND PIPE TODAY(APPROX TOTAL IS 300 BBLS) BBLS CEMENT RECOVERED (DOES NOT INCLUDE CEMENT NOT PUMPED) BBLS CEMENT LEFT IN LINER ,CEMENT 15.8 PPG CLASS "G" CMT CONTAINING 330.5% FL-33 0.1% CD-32 0.35% R-11 1.0 GAL PER SK FP-6L 0.1% S-400 THICK TIME = 7 HRS 22 MIN INCLUDING 1 HOUR SURFACE TIME LAB APl F.L.-- 50 ML @ 170°F (REQUESTED RANGE 40 TO 55 ML) FIELD APl F.L. = 47 ML, 19 MM. LIVE F.L. - 40 ML, 30 MM. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 29 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, · Enclosed, please find the data as described below: WELL 1-33/M-23 # DESCRIPTION 1 PLS FINAL BL+RF 1 GR/CCL FINAL BL+RF 1PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL-BL+RF ECC No. Run # i 2628.09 Run # 1 5709.05 Run ~ 1 Run # 1 5723.06 Run # 1 5933.03 Run # i~ 6483.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 ... Anchorage, AK 99518 563-7803 Received by: o~ ~x ~o ~907~ RECEIVED OCT 0 4 199§ Alaska 0/I & Gas Cons. Commission Date: ' LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 November 1994 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: ~WELL ~%%~~ ~~ ~1-67/T-20 /~3-21/L-34 SDI ~ 3-17/J-30A SDI # DESCRIPTION 1 LDWG TAPE & LISTER 1 PDK-100/GR FNL BL+RF 1 PDK FINAL BL+RF Run # 1 Run # 1 Run # 1 ECC No. 5709.04 5765.06 6185.09 ~-L~--~-gn and return tv: Atlas w'lre~ 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Or F~X to (907) 563-7803 Received by:~~ /~~ ~ //- LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 7 November 1994 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL 1-67/T-20 I~U~4-38/K-34 DESCRIPTION 1 PFC/PERF FINAL BL 1 PFC/PERF FINAL RF 1 PDK/TEMP FINAL BL 1 PDK/TEMP FINAL RF Run ~ 1 Run # 1 ECC No. 4143.08 Run # 1 5709.04 Run # 1 1 PLS ~FINAL BL Run ~ 1 5826.05 1 PLS FINAL RF Run # 1 I PLS FINAL BL Run # 1 5985.10 1 PLS FINAL RF Run # 1 1 PDK/BORAX FINAL BL 1 PDK/BORAX FINAL RF Run # 1 6235.04 Run # 1 P~=~=~_ -_ign a,,u' ~Lu~-n to- 5600 B Street RECEIVED Suite 201 Anchorage, AK 99518 ~0~ Attn. Rodney D. Paulson Or F~ (907) 563-7803 askaOil& GasCons. Co~issio~' Received by: ~ ~. ~~ ~ ~chorago ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 13 September 1994 RE: \ Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ~ 1-55/R-25 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PLS/SPNR FINAL BL 1 PLS/SPNR RF SEPIA 1 PLa/PROFILE FINAL BL 1 PLa/PROFILE RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA ECC No. Run # 1 5601.03 Run # 1 Run # 1 5709.02 Run # 1 Run # 1 5870.02 Run # 1 Run # 1 Run # 1 6235.02 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 2~1 anchor~g~ AK 99518 ~_ J~ney D. Paulson Receive Please sign and return %0.' Petroteehnieal Data Center BP Exploration (Alaska) Ine 900 East Benson Boulevard Anchorage, Alaska 99508 Received by ~ Date: % Date LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 24 September 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL 3-19/R-28 SDI 1-53/Q-20 MPI DESCRIPTION 1 PLS FINAL BL 1 PLS FINAL RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA ~1 DTEMP/PRES FINAL BL BL FINAL 3 P/PRES RF SEPIA - DK/GR/OOL RF SEPIA ECC No. Run # 1 5709.03 Run # 1 Run # 1 6185.07 Run # 1 Run # 1 6217.06 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 6276.00 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 ~__~/ Anchorage, AK 99518 Att~/~,o.~ey D. Paulson ~ ~~~/~~ Date: Received b BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 11, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs fo~ the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, ne L. Haas Senior Technical Assistant II JLH Enclosures xc' File 06.10 WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME 9,'7'---E, I .---1-09/J-18 ~7---'5Z-1-41/O-23 ~q--I Iq--1-67/T-20 ~Yo-~Z.---2-04/M-19 ~ 0-- q~-'2-18/L-16 c~O-' Z-q- 2-36/O-14 ~ 2-1 Z I-3-03/J-33 9/17/93 9/20/93 9/25/93 9/21/93 9/21/93 9/22/93 9/24/93 11500'- 11951' 11050'- 11875' 11300'- 11800' 10300'- 10750' 10800'-11150' 10550'-11350' 13425'- 13725' Production Logging Services PDK-100 Production Logging Services Production Logging Services Production Logging Services PDK-100 Production Logging Services ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE t t ~7o'---- I t STATE OF ALASKA ALA~...,-t OIL AND GAS CONSERVATION COMMISS,,. · REPORT OF SUNDRY WELL OPERATIONS 1 Operations performed: Operation shutdown Stimulate Plugging Pedorate X c,~, Pull tubing Alter casing Repair well 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 2230' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 1143' SNL, 3352' WEL, Sec. 01, T11N, R 16E At effective depth 1418' SNL, 3456' WEL, Sec. 01, T11N, R 16E At total depth 1454' SNL, 3468' WEL, Sec. 01, T11N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-67/T-20 9. Permit numbedapproval number 89-114/92-222 10. APl number 50- 029-21985 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 12150' feet 10614' BKBfeet Plugs (measured) Effective depth: measured true vertical 12050'feet 10521' BKBfeet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True ve~.a~ depth BKB 64' 30" Driven 103' 103' 2459' 13-3/8" 3577 c.f. Permafrost 2498' 2498' 10923' 9-5/8" 575 c.f. Class G 10962' 9536' measured 1730' 7" 643c. f. Class G 10683'- 12413' 9297'-10858 11444'-11454', 11463'-11473', 11488'- 11496'; 11509'- 11525'; 11605'- 11638'; 11499'- 11506'; 11527'- 11552'; 11702'- 11736' true vertical (subsea) 9911'-9920', 9928'-9937', 9951'- 9958'; 9970'- 9984'; 10057'- 10087'; 9961'- 9967'; 9986'- 10009'; 10145'- 10176' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 with 4-1/2"tailpipe to 10748' Packers and SSSV (type and measured depth) 9-5/8" packerat lO664'; 7" WO packerat l1655;~- ~S~V~ at1551' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ,JAN 1 4 993 Alaska Oil & Gas Cons. Commission Anch'orag 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injectiorl Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2299 2065 3566 0 / 3017 / 5689 3141 0 Tubing Pressure 529 642 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned(~)~¢?~ C~'. /~~-~'¢'-'~ TitleSoniorTochnicalAssistantll Form 10.4/¢4 Rev 06/15/88 Date ////~/~5 SUBMIT IN DLIPI'ICATE i Endicott Production Engineering , Department ,, ADDITIONAL PERFORATIONS DATE- 9/26/92 WELL N°: 1-67/T-20 BP EXPLORATION REP: LOVELAND SERVICE COMPANY: ATLAS WIRELINE (DAHL) DATE/TIME I OPERATIONS SUMMARY 0945 MIRU. Post radio silence sign's at the e~qtrance to island and next to well Site. 1015 ESTABLISH RADIO SILENCE AND ARM GUNS (Notif7 security). ,,, 1020 Install SSV fusible cap. FWHP = 550 psig. WHT = 160° F. lAP = 1920 psig. OAP = 175 psig. Choke = 104 BEANS 1021 SI Well. Swab leaked. Wait on grease truck, Grease swab. Pressure test lubricator to wellhead pressure. 1205 RIH with Gun #1 {20 feet). SIWHP = 1750 psig. 1305 Open wing valve and set production choke, to 70 beans. 1320 Tie in to CBL dated 12/10/$9. All of the depths listed below are from this log which is on depth the open hole reference log. FWHP = 620 psi. Rate = 6000 bpd. 1356 Hang gun #la Top Shot at 11463' MDBKB. 1357 Shoot gun #la from 11463 - 11473' MDBKB and flow well for 20 minutes. FWHP = 650 psig. 1420 Drop down and re-confirm tie-in. Hang gun # lb top shot at 11444' MD BKB. 1425 Shoot gun #lb from 11444 - 11454' MDBKB and flow well for 10 minutes. Well began to peg separator. FWHP = 2000 psig, Rate = 10000+ bpd. SI Well. Hope we didn't shoot GAS!! Maybe that was just a slug. 1435 POH. SIWHP = 2750 psig. Confirm all shots fired. 1540 End radio silence. RD. POP. PERFORATION SUMMARY' GUN INTERVAL(DLL) la 11463-11473 lb 11444-11454 CBL DEPTH FEET SUBZONE 11463-11473 10 3C2 11444-11454 10 3C2 All intervals were shot using 3 3/8" carrier guns (Specta Jet) w/21 gr. charges at 4 spf, 90 degree phasing and 45° orientation from Iow side of pipe. glaska 0il .& Gas C0~'~s. gpchoraq.,,, BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICOTT FIELD ONLY WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME // 1-35/O-25o°6-1~q 10/16/92 1-43/P-26 o°~-Io~' 9/28/92 1-47/Q-21o0~.--1) I 1 0/13/92 1-67/T-20 ~"1~ ,~ 9/26/92 2-28/P-19~-'~E' 10/15/92 2-54/Q-12 9/29/92 3-07/N-28~'"1 >'' 9/27/92 3-11/U-30o°g"J? 10/14/92 4-04/T-26 ~'¢--~' 9/28/92 4-06/Q-32~/~$ 10/3/92 9/17/92 SAG DELTA NORTH ONLY 2-3218N-O3~..tl~ 9/19/92 12100'-13150' 12900'-14275' 10750'-11200' 11315'-11600' 9650'-10350' 10620'-12063' 13050'-13300' 12800'-13380' 13000'-14030' 10800'-11482' 13600'-14226' 14000'-14225' 12900'-13278' PDK-100 Gamma Ray/CCL (Borax)~ Injection Profile Survey Production Logging., PFC Gamma Ray PDK-100 Gamma Ray/CCL (Borax) Injection Profile Warm Back Injection Profile Survey .,,- . Production Logging (~J,,,~-~/'~" ~'-~.) Injection Profile Survey ,.-- Production Profile - Pump-In-Temperature Survey PFC//Gamma Ray ~ Production Profile Survey ,,- Atlas Wireline Camco Atlas Wireline Atlas Wireline Atlas Wireline Camco Camco Atlas Wireline Camco Camco Camco Atlas Wireline Ca~ " RE EIVED OCT 5 0 1992 Alaska Oil & Gas Cons. Commission Anchorage AL,-,..,KA OIL AND GAS CONSERVATION COMMISS,~N 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 O[her__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 4. Location of well at surface 2230' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 1143' SNL, 3352' WEL, Sec. 01, T11N, R16E At effective depth 1418' SNL, 3456' WEL, Sec. 01, T11N, R16E At total depth 1454' SNL, 3468' WEL, Sec. 01, T11N, R16E RECEIVED S E P - 2 1992 Alaska Oil & Gas Cons. Commi$= Anchorage 12. Present well condition summary Total depth: measured true vertical Effective depth' measured true vertical 12150' feet 10614' BKB feet 12050' feet 10521' BKB feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) KBE = 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-67 .iT-20 9. Permit number 89-114 10. APl number ,[0fl 50- 029-21985 11. Field/Pool Endicott Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured de~ TrueBv~ical depth 64' 30" Driven 103' 103' 2459' 13-3/8" 3577 c.f. Permafrost 2498' 2498' 10923' 9-5/8" 575 c.f. Class G 10962' 9536' 1730' 7" 643 c.f. Class G 10683' - 12413' 9297'- 10858 measured 11488'- 11496'; 11509'- 11525'; 11605'- 11638'; 11499'- 11506'; 11527'- 11552'; 11702'- 11736' true vertical (subsea) 9951'- 9958'; 9970'- 9984'; 10057'- 10087'; 9961'- 9967'; 9986'- 10009'; 10145'- 1O176' Tubing (size, grade, and measured depth) 4-1/2" 12.6,¢ L-80 with 4-1/2" tailpipe to 10748' Packers and SSSV (type and measured depth) 9-5/8"packer at 10664'; 7" WD packer at 11655'; 4-1/2" SSS V at 1551' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch X 14. Estimated date for commencing operation I 15. Status of well classification as: September, 1992 ' 16. 'If proposal was verbally approved Oil x Gas __ Suspended ~ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signec~~;2~ O:~ ~¢L_~i)___ Title SeniorTechnica/Assistantll Date Conditi~s of approval: Notify Commission so representative may witness A'""'roved ,~.p_.proval No.~...? Plug integrity BOP Test Location clearance F'~ . ~.o-~Jy ~_ Mechanical Integri'---~y Test Su-----bsequent form required 10----~Oz/ ~eturnea Original Signed By Approved by orderofthe Commission David W. Johnston Commissioner Date c~/3/? Form 10-403 Rev 06/15/88 SUBMIT IN tRIPLICATE ENDICOTT FIELD Well 1-67/T-20 Well 1-67/T-20 is an SDI area 3B/3C oil producer. The well is producing 553 BOPD @ 67%wc and solution GOR from the 3C1 and 3B3 sequences. The 3C2 sequence is not perforated, but appears to be a decent quality sand which should significantly increase oil production for the well if perforated. Given the offset from the 3C2 gas cap, no significant increase in gas production is anticipated. Well 1-63/T-22 is too distal to adequately recover these reserves with good areal sweep. 1-63/T-20 is the only well in the region west of the midfield fault which can access the 3C2 reserves. In order to efficiently recover 3C2 reserves and increase the production rate in 1-67/T-20 we request adding perforations at the following depths with 3 3/8" carrier guns @ 4 spf. Sequence Depth MD sDf 3C2 3C2 11444-11454 (Ref. CBL 12/10/89) 4 11463-11473 (Ref. CBL 12/10/89) 4 A lubricator will be installed and tested to 3000 psi for all well work. The SSSV will be reinstalled and tested after the perforations are added. S E P - 2 1992 ~laska Oil & 6as 6o~]s. Commission Anchorage il BASIC SYSTEM MAKEUP BOWEN PACKOFF' l-'-- HAND .PUMP ~SE SEAL ' I::LO~BE FLOWLINE GREASE LINE FLOWLINE VALVE GREASE MANIFOLD GREASE PUMP: RISER GREASE RESERVO. BOP RECEIVED S E P -- 2 1992 Alaska 0il & Gas Cons. CommissiOn Anchorade' BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICO'I-I' FIELD ONLY WELL NAME DATE INTERVALS LOG NAME Bluelines to the State RUN NO COMPANY NAME 3.01/N.29o°~'-I'~~ 3-05/0-29 3-45/M-39 4-06/Q-32 4-44/M-44 1-27/P-20~?-~' 6/13/92 1-37/P-24 o°?'"~/o 6/27/92 1-57/R-23 ~'"//~ 6/15/92 1-67/T-20 o~?'''//¢' 6/2/92 1-69/V-19 /eo--~-~' 6/1/92 2-04/M-19 ~"~2"' 6/18/92 2-52/8-14,~?-'~ ''~'''' 6/15/92 6/1/92 3/23/92 6/9/92 6/10/92 f6/22/92 6/17/92 6/2/92 9950'-10690' 12050'-12430' 11600'-1 2389' 10550'-11800' 12000'-12630' 10000'-1 0675' 10600'-12667' 12150'-12844' 12000'-12520' 11800'-12500' 10000'-11534' 13600'-14237' 13900'-14316' 13600'-14500' Compensated Neutron Log 2.5" CNL Leak Detection Survey Temperature Gamma Ray Log Gas Lift Survey Collar Log Injection Profile Survey TDT-P Jewelry Log Production Profile Survey Perforation Log Casing Collar Log Jewelry Log PFC/Gamma Ray '/''' Pump In Temperature Survey Temperature CCL Log One One One One One One One One One One One One One One Schlumberger Camco Camco Camco Camco Schlumberger Camco Camco Halliburton Logging Services Atlas Wireline Services Camco Atlas Wireline Services Camco Camco Page 1 John Boyle August, 20, Page 2 1991 WELL 1-67/T-20 11250'-11800' / FULL BORE PRODUCTION LOGS V SCHLUMBERGER 7/31/91 RUN TWO WELL 2-64/U-10,~' 13600'-14600' NJ. PROFILE STEP RATE SURVEY 7/2-6/91 RUNONE WELL 3-21/L-34~/ 12300'-12645' TEMPERATURE SURVEY 6/30/91 RUNONE WELL 3-23/N-32 ¢ 10500'-11500' PRODUCTION LOC-~ING SERVICES ATLAS WIRELINE 7/12/91 RUNONE WELL 3-25/M-27 V' 13500'-13976' STATIC TEMPERATURE SURVEY CAMCO. 13000'-13964' v/ PRODUCTION PROFILE SURVEY 7/1 5/91 RUNONE 6/28/91 RUNONE WELL 4-08/P-27,/ 13000'-13250' STATIC TEMPERATURE SURVEY 6/22/91 RUN ONE Sincerely, J/~ Haas JLH/clt xc- File 6.10 2142/J L H/clt Alaska Oil Gas Conservation Commission .300i Porcupine Drive Anchorage, Alaska .99501-3192 907-279-1433 , / Receipt of the following material which was transmitted via is hereby acknowledged: EL~gl¥ L. ~rp'l /C/J L AUG,.!] 2 1991i C~ c :--- .... /: ' / 'i! /' ~ Copy sent to sender: Yes No f' June 13, 1991 Alaska Oil and Gas Conservation Commission Page 5 WELL 4-14/R-34 TEMPERATURE LOG 10000'-10640' HRS 5/21/91 RUNONE Sincerely, ~/L. Haas JLH/clt xc: File 6.10 2013/JLH/clt R£C IV D JUN 1 7 199~ Alaska 0il & Gas Cons. commission Anchorage WELL 1-55/R-25 RADIOACTIVE TRACER SURVEY 12950'-13550' SCHLUMBERGER 8/12/90 RUN ONE ,/ STATIC PRESSURE SURVEY 12950'-13550' SCHLUMBERGER 8/12/90 RUN ONE WELL 1-57/R-23 ~/TEMPERATURE SURVEY 11486'-11972' HALLIBURTON LOGGING SERVICES 8/14/90 RUN ONE WELL 1-63/T-22 STATIC PRESSURE SURVEY 12436'-12436' SCHLUMBERGER 8/13/90 RUN ONE RADIOACTIVE TRACER SURVEY 12300'-13082' SCHLUMBERGER 8/13/90 RUN ONE WELL 1-67/T-20 /TEMPERATURE SURVEY 111 20'- 11650' HALLIBURTON LOGGING SERVICES 8/12/90 RUN ONE WELL 2-26/N-14 STATIC TEMPERATURE SURVEY 11500'-12000' CAMCO 8/12/90 RUN ONE WELL ~-28/p-19, PERFORATION RECORD 10070'-10436' SCHLUMBERGER 8/22/90 RUN. ONE WELL 2-34/P-14 INJECTION PROFILE WARM BACK 10770'-10990' CAMCO 8/1/90 RUN ONE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevarcl P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 6, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-HQle Pressure Reoorts Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells Well Name Date 1-21/K-25 8-14-90 1-67/T-20 8/12/90 2-26/N- 14 8-12-90 2-36/O-14 7/14-15/90 2-46/Q- 15 8-13-90 2-52/S-14 8-13-90 3-41/K-39 8-11-90 4-18/S-30 8-13-90 4-26/0-34 8/11/90 4-42/P-38 8/10/90 4-46/N-39 8/12/90 5-01/Sag Delta #7 8/10/90 5-02/Sag Delta #10 8/15/90 If there are any questions regarding this data, please contact Jeanne Haas at 564-5225. Sincerely, ~'anne L. Ha~.s R E' EIVED SEP 11 1990 ·asP, a.OiJ.& Gas Cons. ~ommission ~chorage *TMD ~ 12750' - 14222' Halliburton Run No. 1 ..,W,.. ELL 1-63/T-22 *TEMPERATURE SURVEY 12180' - 13093 Run No. 1 Camco WELL 1-67/T-20 ~ *PRODUCTION PROFILE-" '11275' - 11800' Run No. 2 Camco WELL 1-6~/V-19 *DUAL LATEROLOG 11521' - 12994' Halliburton *SPECTRAL DENSITY -~'" 11524' - 12994' Halliburton *RFT Run No. 1 Halliburton Run No. 1 Run No. 1 *CET 3100' - 12898' Schlumberger *CBT 3100' - 12872' Schlumberger *PERFORATING RECORD 11125' - 12874 Schlumberger WELL 2-04/M-19 *PRODUCTION PROFILE 10300' - 10685' Camco Run No. 1 Run No. 1 Run No. 1 Run No. 1 WELL 2-14/O-16 *PRODUCTION PROFILE 10300' - 10998' Camco Run No. 1 .WELL 2-18/L-16 *DUAL LATEROLOG 10100' - 11428' Atlas Run No. 1 WELL 1-43/P-26 *THERMAL DECAY-BORAX LOG (TDT-P) 13200' - 13828' Run No. 1 SCHLUMBERGER WELL 1-45/Q-26 *COLLAR LOG 13418' - 13891' Run No. 1 ATLAS WlRELINE SERVICES WELL 1-47/C)-21 *HRS 10600' - 11299' HRS Run No. 1 WELL 1-49/P-21 *TEMPERATURE SURVEY 10800' - 11290' Run No. 1 CAMCO WELL 1-67/T-20 *COLLAR LOG 11097' - 11588' Run No. 1 ATLAS WlRELINE SERVICES *COLLAR LOG 11400' - 11710' Run No. 1 ATLAS WIRELINE SERVICES WELL 2-26/N-14 *PERFORATING RECORD 11650' - 12020' SCHLUMBERGER Run No. 1 Run No. 1 *TEMPERATURE LOG 11000' - 11800 CAMCO *CCL- GAMMA RAY LOG 10680' - 12100' SCHLUMBERGER Run No. 1 WELL 2-28/P-1~ *PRODUCTION PROFILE 9900' - 10452' CAMCO Run No. 1 BP EXPLORATION March 14, 1990 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 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 1-09J-18 2-12-90 1-41/O-23 2-18-90 1-49/P-21 3-1-90 1-67/T-20 2-3-90 2-26/N-14 2-7-90 2-28/P-19 2-24-90 2-52/S-14 1-2-90 3-17/J-30 2-27-90 4-04/T-26 12-30-89 4-42/P-38 2-13-90 4-46/N-39 12-29-89 5-03/SG09 2-20-90 If there are any questions regarding this data, please contact Jeanne Haas at 564-5225. Sincerely, dLH Enclosures *DUAL LATEROLOG MICROSHERICALLY FOCUSED LOG 13482' - 14090' Run No. 1 HALLIBURTON *CEMENT EVALUATION LOG (CET) 12500' - 13985' Run No. 1 SCHLUMBERGER *CEMENT BOND LOG (CBT) 12500' - 13965' Run No. 1 SCHLUMBERGER *TCP GUN POSITIONING LOG 13454' - 13750' Run No. 1 SCHLUMBERGER WELL 1-45/Q-26 *CEMENT BOND LOG (CBT) 12792' - 14181' Run No. 1 SCHLUMBERGER *CEMENT EVALUATION LOG (CET) 12792' - 14181' Run No. 1 SCHLUMBERGER *GRCCL- PACKER RECORD 12850' - 14172' Run No. 1 SCHLUMBERGER WELL 1-67/'1'-;~0 *GAMMA RAY TEMP LOG 11500' - 12041' CAMCO Run No. 1 WELL 2-52/S-14 *TEMPERATURE SURVEY 11600' - 12670' Run No. 1 CAMCO WELL 3-01/N-2~) *DUAL BURST TDT LOG (TDT-P) 11845' - 12947' Run No. 3 SCHLUMBERGER BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 15, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn' Mr. C. V. Chatterton Well 1-67/T-20 (Endicott) Enclosed, in duplicate, is form 10-407, our Report of Well Completion for the above named well. This information reflects the current condition and status of the well. Enclosed are two copies each of daily drilling reports, directional and gyroscopic surveys. The open hole logs were sent under separate cover by the Endicott Development Group. Yours very truly, M. E. Miller Endicott Lead Engineer MEM/KTH Enclosures (3) RECEIVED J. Oldenburg (MB 7-1) Endicott WlO's w/4 Well File AnchoraG~ STATE OF ALASKA ALASF~-~ OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 89-114 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21985 4. Location of well at surface 9. Unit or Lease Name 2230' SNL, 2224' WEL, SEC. 36, T12N, R16E ~~.~,~" Duck Island Unit/Endicott At Top Producing IntervalI"~'""~'~°I YEi~IFi'ED 10. Well Number 1-67/T-20 MPI 1143'SNL, 3352' WEL, SEC. 01, T11N, R16E : $~,rf~.~_~. 11. Field and Pool Depth ~. H, ~ Endicott Fie/d/Endicott Pool At Total 1454' SNL, 3468' WEL, SEC. 01, T11N, R16E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 55.1' I ADL 34636 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.,./__$usp. or Aband.,_,115' Water Depth. if offshore 116. No. o! Completions 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12150'MD/10614'TVD 12050'MD/10521'TVD YES [] NO [] I 1551'feet MD I 1466' 22. Type Electric or Other Logs Run DLL/MSFL/GR, DIL/GR, RFT (in 8-1/2" hole), GR/DIL/FWS (in 12-1/4" hole) 23. CASING, LINER AND CEMENTING R~ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'rl'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Drive 103' 13-3/8" 68# NT.8OCYHE Surface 2498' 17-1/2" 3577 cu fl Permafrost 9-5/8" 47# NT80S Surface 9551' 12-1/4" 9-5/8" 47# NT95HS 9551' 10962' 12-1/4" 575 cu ft Class G 7" 29# NT95HS 10683' 12413' 8-1/2" 643 cu fl Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MDI Schlumberger 3-3/8" @ 4 spf 4-1/2"12. 6t/L-80 10748' 10664' MD TVDss 7"x4-1/2" Pkr 11669' 11655' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11527'-11532' 9986'-9991' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11605'-11638' 10057'-10087' 13-3/8"X 9-5/8" Downsqueezed annulus w/161 bbls dead 11702'- 11736' 10145'- 10176' crude. 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) January 22, 1990 I Flowing Date of Test Hours Tested PRODUCTION FOR DIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED ~)IL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED: !~iaska Oi~ & ~aas (':onto Comrnissio~ : ~ Anchoraffo Form 10-407 Rev. 7-1-80 ~INUED ON REVERSE SIDE Submit in duplicate GE(~OGIC MARKERS F~. ~TION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top HRZ 10646' 9211 Itkilyariak 10942' 9464' Top Kekiktuk 11324' 9803' ! 31. LIST OF ATTACHMENTS , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe~J~_ _--~ '~-~ ~~__~TitleEndicottLeadEn.q[noer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on ali 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 November 14, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 API: 50-029-21985 AFE Amount: Current Amount: 0600 Depth: 1350' Day: 1 24- Hour Ftg: . 1350' Current Operation: Drilling. Spud well 0800 hrs. 11-13-89. Drill and survey 17-1/2" hole to 1350'. Mud Type: SPUD MUD WT: 9.3 SURVEY MD ANGLE VIS: 200 PV: YP: FL: DIRECTION .TVD SECTION Solids: Temp: °F COORDINATES_ DLS B~ Daily Drilling Report -- ENDICOTT November 15, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 API: 50-029-21985 AFE Amount: Current Amount: 0600. Depth: 2510' Day: 2 24- Hour Ftg: 1160' Current Operation: Running 13-3/8" casing. Drill and survey 17-1/2" hole to 2510'. Circulate hole clean. POH. Mud Type: SPUD MUD WT: 9.9 SURVEY MD ANGLE VIS:95 PV: YP: FL: DIRE(7I'IQN TX(D,.. SECTION Solids: Temp: 50 °F COORDINATES, DLS BP EXPLORe;lION Daily Drilling Report -- ENDICOTT November 16, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 API: 50-029-21985 AFE Amount: Current Amount: 0600 Depth: 2510' Day: 3 24- Hour Ftg: 0 Current Operation: Install wear ring. Run and cement 13-3/8" casing. Install wellhead. NU and test BOP. Mud Type: LSND SURVEY MD, WT: 9.0 VIS: 43 PV: 5 YP: 25 FL: 19 ANGLE DIRECTION TVD SECTION Solids: 4 Temp: COORDINATES BP EXPLOR~N Daily Drilling Report-- ENDICOTT November 17, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 APl: 50-029-21985 AFE Amount: Current Amount: 0600 Depth: 3500' Day: 4 24- Hour Ftg: 990' Current Operation: Repairing hook lock. Test 13-3/8" casing to 3000 psi. - OK. Drill cement. Drill 12-1/4" hole to KOP at 3500'. POH for motor. Mud Type: LSND SURVEY MD 9 3261 WT: 9.2 VIS: 40 PV: 5 YP: 12 FL: 22 Solids: 6 Temp: 72 °F ANQLE DIRE~I'IQN ~ SECTIQN COORDINATES DL$. 1 N53E 3261 -2 1 12 0.2 Rig: DOYON 15 Well: 1-67ff-20 (MPI) Daily Drilling Report -- ENDICOTT November 20, 1989 at 0600 hrs AFE # 717574 API: 50-029-21985 AFE Amount: Current Amount: Current Operation: 0600 Depth: 7276' Day: 7 72- Hour Ftg: 3776' with bit. Drill and survey 12-1/4" hole to 7276'. Mud Type: LSND SURVEY 20 25 31 WT: 9.7 VIS: 37 PV: 7 MD ANGLE DIRECTION TVD 5080 34.7 S16W 4991 5993 40.4 S15W 5686 7132 37.8 S13W 6570 YP: 10 FL: 9.0 Solids: 9 Temp: SECTION 433 1033 1748 COORDINATES S439 W87 S 1006 W250 S1703 W422 80°F DLS 2.8 0.4 0.2 BP EXPLORATION Daily Drilling Report -- ENDICOTT November 21, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 APE 50-029-21985 AFE Amount: Current Amount: 0600 Depth: 8125' Day: 8 24- HourFtg: 849' Current Operation: Drilling. Drill and survey 12-1/4" hole to 8125'. Mud Type: LSND SURVEY ~ 35 7953 WT: 9.7 VIS: 40 PV: 8 ANGLE DIRECTION TVD 39.4 S14W 7213 YP: 12 FL: 9.0 SECTION 2256 Solids: 9 Temp: 72 ~F COORDINATES DLS S2199 W544 0.3 BP EXIR. OR~N Daily Drilling Report -- ENDICOTT November 22, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 API: 50-029-21985 AFE Amount: Current Amount: 0600 Depth: 8687' Day: 9 24- HourFtg: 562' Current Operation: Cut drilling line. Drill and survey 12-1/4" hole to 8687'. Trip for bit. Mud Type: LSND .,SURVEY MD, 38 8519 WT: 9.8 VIS: 38 PV: 8 YP: 12 FL: 7.9 ANGLE DIRECTION TVD SECTION. 41.2 S13W 7645 2620 Solids: 10 Temp: 92 °F COORDINATES DL$ S2555 W628 0.3 BP EXPLORATION Daily Drilling Report -- ENDICOTT November 27, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 APl: 50-029-21985 AFE Amount: Current Amount: 0600 Depth: 10620' Day: 14 120- HourFtg: 1933' Current Operation: Drilling. Drill and survey 12-1/4" hole to 10620'. Mud Type: LSND SURVEY 41 44 48 WT: 10.2 VIS:40 PV: 14 MD ANGLE DIRECTION TVD 9083 41.6 S14W 8070 9646 41.7 S15W 8490 10403 37.1 S15W 9072 YP: 9 FL: 5.2 SECTION 2996 3370 3853 Solids: 13 Temp: C.,OORDINATE$,, S2922 W719 S3284 W813 S3753 W939 100 °F .DL8 0.1 0.1 0.9 BP EXPLORATION Daily Drilling Report-- ENDICOTT November 28, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 API: 50-029-21985 AFE Amount: Current Amount: 0600.Depth: 10977' Day: 15 24- HourFtg:' 357' Current Operation: POH to run logs. Dr/Il and survey to 12-1/4" hole TD at 10977'. Circulate and condition hole. Mud Type: LOW SOLD WT: 10.2 VIS:39 PV: 14 'SURVEY MD ANGLE DIRECTION TVD 51 10977 29 S19W 9553 YP: 10 FL: 5.0 SEgTION 4165 Solids: 13 Temp: 104 °F COORDINATES. DLS S4047 W1029 1.2 BP EXPLORATION Daily Drilling Report-- ENDICOTT November 29, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/%20 (MPI) AFE # 717574 APl: 50-029-21985 AFE Amount: Current Amount: 0600Depth: 10977' Day: 16 24- HourFtg: 0 Current Operation: RU to run 9-5/8" casing. Run open hole logs in 12-1/4" hole. Make wiper trip to condition hole for casing. Mud Type: FW/LIG SURVEY MD WT: 10.3 VIS:41 PV: 15 YP: 11 FL:5.0 Solids: 14 Temp' .ANGLE DIRECTION TVD SECTION COORDINATES 86°1: DLS BP EXPLORJ~;ilON Daily Drilling Report -- ENDICOTT November 30, 1989 at 0600 hfs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 API: 50-029-21985 AFE Amount: Current Amount: 0600Depth: 10977' Day: 17 24- Hour Ftg: 0 Current Operation: Stringing blocks to I0 lines. Run and cement 9-5/8" casing. Test BOPE. MudType: FW/LIG WT: 10.3 VIS:40 PV: 14 SURVEY MD ANGLE DIRE ~'TIQN. TVD YP: 10 FL: 5.0 SECTIO,..N Solids: 14 Temp: °F COORDINATES DL~, 4> BP EXPLOR~;i'ION Daily Drilling Report -- ENDICOTT December 1, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 APl: 50-029-21985 AFE Amount: Current Amount: 0600 Depth: 11050' Day: 18 24- Hour Ftg: 73' Current Operation: Drilling. Drill out cement from 9-5/8" casing. Drill 8-1/2" hole to 11050'. Mud Type: FW/LIG SURVEY MD WT: 9.6 VIS:34 PV:5 ANGLE DIRECT. I, QN. TVD YP: 8 FL: 9.2 SECTION Solids: 8 Temp: 84 CF COORDINATES DLS. BP EXPLORATION Daily Drilling Report-- ENDICOTT December 4, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 API: 50-029-21985 AFE Amount: Current Amount: . 0600Depth: 11920' Day: 21 72- HourFtg: 870' Current Operation: Drilling. Drilled 8-1/2" hole to 11920'. Mud.Type: FW/LIG SURVEY ,MD, WT: 9.8 VIS: 37 PV: 8 ANGLE DIRECTION TVD YP: 7 FL: 5.8 SECTION Solids: 8 Temp: 103 °F COORDINATES DL$ BP EXPLOR/I~ON Daily Drilling Report -- ENDICOTT December 5, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 Al)I: 50-029-21985 AFE Amount: Current Amount: 0600 Depth: 12150' Day: 22 24- Hour Ftg: 230' Current Operation: Running open hole logs. Drilled 8-1/2" hole to TD at 12150'. Condition hole for logs. Run logs: DLL/MSFL/GR, SLD/CNT/GR. Mud Type: FW/LIG ,~,UR,VEY MD WT:9.9 VIS:38 PV:8 YP: 10 FL:6.0 Solids:9 Temp: 105~F ANGLE DIRECTION TVD SECTION COORDINATES DL$ BP EXPLOR~N Daily Drilling Report .- ENDICOTT December 6, 1989 at 0600 hfs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 APl: 50-029-21985 AFE Amount: Current Amount: 0600 Depth: 12150' Day: 23 24- Hour Ftg: 0 Current Operation: Fishing for log~4ng tool. Attempt to run open hole logs. Stuck log~ng tool and pulled wireline out of tool head. Mud Type: LW/LIG WT: 9.9 VIS' 37 PV: 6 YP: 8 FL: 7.8 Solids: 9 Temp: SURVEY ,MD. ANQLE DIRE~'I~IQN TVD SECTION COORDINATES 89°F DL$, BP EXPLORe;lION Daily Drilling Report-- ENDICOTT December 7, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 APE 50-029-21985 AFE Amount: Current Amount: · 0600 Depth: 12150' Day: 24 24- Hour Ftg: 0 Current Operation: Running open hole logs. Fish and recover log~ng tool. Make wiper trip. Mud Type: LIGNO WT: 9.6 VIS: 39 PV: 8 ANGLE DIRECT[ON TVD YP: 8 FL: 6.8 SECTION Solids: 8 Temp: 90 °F ,~.OORDINATES DLS BP EXPLOR~N Daily Drilling Report -- ENDICOTT December 8, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 API: 50-029-21985 AFE Amount: Current Amount: 0600 Depth: I2150' Day: 25 24- Hour Ftg:' 0 Current Operation: Cementing 7" liner. Complete log~ng DIL, RFT. Make wiper trip. Run 7" liner on 5" drill pipe. Circulate and reciprotate. Mud Type: LIGNO SURVEY MD. WT: 9.6 VIS: 39 PV: 8 YP: 8 FL: 6.8 Solids: 8 Temp: - °F ANGLE DIRECTION TVD. SECTION CQORDINATES DLS 8P E~q. ORA]'iON Daily Drilling Report-- ENDICOTT December 11, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67/T-20 (MPI) AFE # 717574 APE 50-029-21985 AFE Amount: Current Amount: 0600 Depth: 12050' PBTD Day: 28 72- Hour Ftg:· 0 Current Operation: Running 4-1/2" robing. Cement 7" liner; shoe @ 12143'. Drill cement out of 9-5/8" casing and 7" liner. Displace well to 9.6 ppg filtered brine. Test liner and lap to 3000 psi - OK. Run CET/CBT. Run and set 7"WD packer. Mud Type: BRINE SURVEY MD WT: 9.6 VIS: PV: YP: FL: Solids: Temp: ~F ANGLE DIRECTION TVD SECTION (?OORDINATES DLS BP EXPLORATION Daily Drilling Report-- ENDICOTT December 12, 1989 at 0600 hrs Rig: DOYON 15 Well: 1-67fr-20 (MPI) AFE # 717574 API: 50-029-21985 AFE Amount: Current Amount: 0600 Depth: 12050' Day: 29 24- Hour Ftg: 0 Current Operation: Rig released. Run 4-1/2" tubing. NU tree and test to 5000 psi - OK. Displace tubing to diesel. Set packer and test to 3000 psi - OK. Test 9-5/8" X 4-1/2" annulus to 2500 psi - OK. Release rig from Well 1-67/T-20 at 0400 hrs. 12/12/89. Mud Type: BRINE SURVEY MD WT: 9.6 VIS: PV: YP: FL: Solids: Temp: ~F ANGLE DIRECTION .TVD SECTION COORDINATES. DLS GREAT I2%ND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY BP EXPLORATION COMPANY MPI 1-67/T20 WELL NAME ENDICOTT, ALASKA LOCATION ALl189D44 GYRO & MWD JOB NUMBER TYPE SURVEY DIRECTIONAL BRIAN WEST SUPERVISOR NAME TITLE SIGNATURE 494 FT 10977 FT mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm! DEPTH INTERVAL FROM TO DATE SURVEY TAKEN 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 CONFIDENCE. MICROFILMED GREAT I. 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A,'~ DR ] FT TRi..IVF.RT S JR,--,FA SFCT ! ON D I RECT ] C~ RFI AT ! VF COORD ! NATFS Cl. OSLIRF DFPTH FIG 10783 Fi]. 1.2 9A~0_3~ 932~.~ 40~.4~ ~ ~7.00 ~ ~9~G_~O .~ 993.0R W 4078.?~ g 1.4 F; 37 W ~.OR7S ?~ 54 94~]..33 ~40~.?]. 43.3.0.~], S ].R.O0 ~ 400]..07 S 3.007.44 ~ 4;i.P~.~ S ~.4 7 S? ~ EffgG t F de_q/;I 0 'I . .1, ! --<47/TPO DATA INTERPOLATED FOR EVEN .1.00 FFFT OF RURREA DEPTH ~FAR. TRU VERI' SI_IR REA MD--TVD VFRTICAL. DFPTFI DEPTH DEPTH B]FF. CORRFCT 5F; 55 0 0 0 1. RE .1.55 .1.00 0 0 ?F;R PR~ ~00 0 0 ~ ~SF; ~00 0 0 ~ ~5 400 0 0 RFIATIVE CC~iRDINATER FRC~ WFi.I.-HEAD 0.00 N 0.00 F 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 F 0.00 N 0.00 F .1.0,..5 1055 .1.000 0 0 0 94 R ,..73 F: .1..1.55 1..1.55 .1..1.00 0 0 0.99 R 3.58 F 1PF, F, 1,.5,.~ ].~00 0 0 1.. 04 S 4.43 F 1 :'455 .1.3,.~R .1.300 0 0 :l.. O? ,-, 5. P7 E .1.455 -1.455 ].40,0 0 0 ]._ :1.4 S ~..I~P. E ].555 3.555 3.500 0 0 0.9~ R ~.74 F ].~55 .1.455 1400 0 0 0.44 S 7.17 F ~.755 1755 .1.700 0 0 0.00 N 7.gO E ].85R .1.855 .1.800 0 0 0_4~ N R.OR F PORS ROSS ~000 0 0 i.P]. N 8.43 E PI. RS ~.1.55 P].O0 0 0 .1..RR N 8.03 F PPSR ~55 ~P00 0 0 "' ]..4~ N 7.~ E ?RES ~555 ~RO0 0 0 0.~ N 7.24 E F'4RR P455 ~400 0 0 0..1.! R ~_87 E ~RRR ~RRR ~500 0 0 0.98 R ~.94 E ?~55 ~g55 2~00 0 0 1.78 S 7.1t E P755 ~7RR ~700 0 0 2.38 R 7.R0 F PRRR 2~R ~00 0 0 ~.54 R 8.].]. E PgRR PgRR ~00 0 0 P.70 R R_7~ F 1-47/T20 DATA TNTFRPOLATED FOR EVEN 100 FEET OF SURSFA DFPTH MFAS. DFPTH 305~ TRU VFRT SL~ SEA MD-TVD VFRTICAI DEPTH DEPTH DJFF_ CORRECT 3055 3000 0 0 3J.~ ~100 0 0 3255 3200 0 0 ~°RR 3300 0 0 ~... ~ ~.. ~RR 3400 0 0 ~!__~. ~.. - RFIAT]VF COORDTNATF~ FRL'~ WFI.t.-HEAD 2.79 S 9.39 E o 24 ~' 10 St~ F 1.49 S !1..74 E 0.71 S I3..4..3 E 0.08 S 15.e;:'.0 F .,555 3655 3856 3958 3555 3500 3655 3~00 3755 3700 3RSF; 3800 ~,.,.,~, o. O0 J.47 S 17.42 5.6~ S 18.50 12.30 S 17.40 22_88 S ].4_49 38.R0 S ?.~0 40~0 437? 4055 4000 S 2 4155 4100 7 2 4255 4200 I1 4 4355 4300 17 6 44,SS 4400 23 ~ S7.2~5 S 3.,50 F. 7.9.84 S 3.65 W 'I07.32 F; J.O.~l W J39_J8 ?', 17.45 W :t7:4.33 S 24.28 W S038 4SSS 4500 30 7 4~55 4~00 39 4755 ~700 SO 4855 4800 495R 4900 83 18 212.53 S 31.47 W .oS. J.4 S 40_.-'q]. W o02 4~. ~ Si ,4,4 W 354.34 S ,SS. 32 W RPRR S4PP 5SSS 'SOSS SO00 105 22 R'~ F; 28 .... l.,.~S .!00 ]33 5255 S200 !87 34 5355 5;300 200 33 545~ S400 233 33 484.19 S I01_37 W S6].SP S J23_Rk W 646.03 S 147_78 W 730_19 S 172.89 W 8].3.98 S !98.S0 W 5820 4084 4214 SSSS 5500 2~S 32 897.38 S 5955 5~00 297 32 980.49 S S7SS 5700 329 32 1042.91S SSSS S800 359 30 1144.57 S SgSS 5900 389 30 I225.17 S 223.1d W 245.90 W 247_45 W 287.84 W 307.94 W T-~T/T?O DATA ]NTFRRDI.ATFD FOR EVEN 1.00 FFFT OF SURRFA DEPTH MFAS. TRU VFRT SUB SEA Iv['..~--TVD VERTICAl DEPTH DFPTH DEPTH D!FF_ CORRFCT ~474 6055 (;000 419 RO ~0~ ~1~5 6!00 448 ~9 69~8 645S 6400 531 28 71J.? 7P~9 749~ 76?0 6555 6500 SS7 o_.-.: 66FiS 6600 S84 ~7 685~ 6800 638 pa 7748 7877 8007 81.57 7055 7000 693 28 7155 71.00 7P? 29 7?55 7?00 757 30 7355 7300 78? 30 7455 7400 812 30 8399 7555 7500 844 3P 8557 7655 7600 877 ~3 f{d6S 7755 7700 9!.0 33 8798 '7855 7800 943 33 893! 7955 7900 978 33 9085 8055 8000 10!0 34 91,98 81.5B 8100 I043 33 9RR~ 8~S 8200 1077 54 9467 8355 8300 1.!1~ 35 9601. 8455 5400 1146 34 10P58 8955 ~900 1.303 29 REI.AT]VE CC~RDINATFR FRC~ WFI,I-HFAD !304.88 g 3P7.8! !.383_75 S 347.25 1.461.57 g 36d.00 1.6J. 5.I5 S 403.33 !890_74 S 4~1..47 1766.30 R 439.03 184P.03 S 4~6.93 !918.36 S 475.~5 2073.09 S 51.3.38 W 2151.99 S 53P.40 W 223.'I._80 S 55! .88 W P3.1.?_ 63 c:"' ..,7!w' .50 W 2394_87 S 59,0. =3 P478_40 S 609.8!. PBdP.99 ~ 829.4? P648.04 S 650.13 ~733.41S ~70.88 3905 09 o ... _ o 713 10 W P991.37 S 734.6I W 3077.87 S 7~.54 W 3420.75 S 848.P0 3~84.70 ~ 891.53 3663.40 S 91,~..88 DATA ]NTFRPOI.ATFD FOR FVFN ]00 FFFT OF SURSFA DFPTH NFAR. TRU VFRT SUR SFA ND-TVD VFRT]CAI DFPTH DFPTH DFPTH DIFF. CORRFCT !0Si0 9JSS 9100 ].BSS 24 !0~ 9~55 9?00 3.377 ~? ~.07E;3 9355 9~00 ~3~6 37 30R~8 94S5 9400 14].3 17 RFI.ATIVF COORDINATFS FRC~ WFI!.-HFAD :~'.,' 39.59 S 38:t. 1 34 '-' 3878.32 S ..... .~ 9S0. "7£~, 969.77 988.4F; Ti. 00e3. :_-34 C ] -.,47/T?0 DATA INTFRPO1.ATED FOR FVEN 1000 FFFT OF MFASURFD DEPTH M. FAR. TRU VF. RT SUB SFA RFI.A'f'IVF CC~DRDINATFS DFPTH DF. PTH DEPTH FROM WFI i.--HFAD ........ .,e .... _ ?- .... ,r.. 7'000 ~.000 .1.94S :I. ;i. 3 N 8.66 RO00 3000 ~94S 2.78 S 8.99 4000 3997 394? 4S .qS o 7 '"'_1 · 7! _~5 .r-lo 00 4??4 48~59 39-'6. d41..5--; ¢5000 ..q,Sg]. ~A3~ 10 I0 ~"":-! .q o~ o .. 7000 6466 (:;4~11. I.~P3.7.9 .q 405.40 W ~000 7~0 7~.9~ ~7.7S R 5~0.8F; W 9000 8007 795P ?863.5? S 70P.73 W 0000 87R6 R70 ] 3504. PO S 870.56 W 55O ilO0 i650 2200 2750 3300 3850 T 4400 ¥ 4950 D 5500 VERTICAL SECTION BP EXPLORATION 1-67/T20 SECTION AT S 19.14 W TVD SCALE: 1 inch = ilO0 feet DEP SCALE: t inch = ilO0 feet DRAWN : 12/6/89 6050 8600 7i50 7700 8250 8800 9350 9900 ................ -§50 0 §§0 ilO0 i6~0 2200 2750 3300 Departure 3850 4400 4950 5500 8050 It~ke~ I~tlftcutl~n III ~ ~ ~J~ 0 0 0 BJ TO t0~77 ~]550 4t50 PLAN VIEW BP EXPLORATION 1-67/T20 CLOSURE: 4~76 ft S 14.2 W DECLINATION: 30.60 deg E SCALE : i inch = ?00 feet DRAWN: 12/6/89 350 700 i050 i400 i750 2i00 2450 2800 3i50 3500 3850 4200 4550 3850 2800 2450 2t00 ~750 1400 1050 700 3500 3i50 350 350 ORIGINAL $ UB-S URFA CE DIRECTIONAl. SURVEY ~---'] UIDANCE [~]ONTINUOUS ~100L Company Well Name- Field/Location BP EXPLORATION 1-67/T-20 MPI (2230' SNL,2224' WEL,SEC 36,T12N,R16E) ENDICOTT, NORTH SLOPE, ALASKA Job Reference No; 73609 Logged By: MCBRIDE HICROFILMED Date /0/o3 q/0l_) .... __,:. Computed By_: ' ' KOHRING GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR BP EXPLORATION 1-67/T-20 NPI ENDICOTT NORTH SLOPEr ALASKA SURVEY DATE: Il-DEC-lO89 ENGINEER: MCBRIDE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZINUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZINUTH OF SOUTH 15 DEG 23 NIN WEST CO#PUTATION DATE: OI-NAR-90 PAGE' 1' BP EXPLORATION 1-67/T-20 ENDICOTT NORTH SLOPE~ ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG PlTN DEG MIN DATE OF SURVEY: 21-DEC-1989 KELLY BUSHING ELEVATION: 55.10 FT ENGINEER: MCBRIDE INTERPOLATEO VALUES FOR EVEN 100 FEET OF.MEASUREO OEPTH VERTICAL DOGLEG * RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH 0000 0o00 -55.10 0 0 N 0 0 E 100000 100.00 44090 0 14 S 5 54 E ZO0. O0 ZO0.O0 144090 0 16 S 32 55 E 300.00 300.00 244.90 0 16 S 61 46 E 400.00 400.00' ' 344090 0 12 N 76 16 E 500.00 500.00 444.90 0 6 N 26 32' E 600.00 600.00 544.90 0 4 N 50 58 g 700.00 TO0.O0 644090 0 8 S 41 44 g 800.00 800.00 744.90 0 11 S 8 37 M 900.00 900.00 844.90 0 18 S 14 19 E 0 23 S 31 30 E 0 25 S 51 51 E 0 18 S 55 47 E 0 20 S 48 51 E 0 29 S 38 28 E 0 23 S 39 44 E 0 20 S 52 0 E 0 14 S 78 37 E 0 34 N 73 56 E 0 34 S 88 12 E 1000.00 999.99 944.89 1100.00 1099.99 1044.89 1200.00 1199.99 '1144.89 1300000 1299099 1244.89 1400.00 1399.99 1344089 1500.00 1499098 1444.88 1600000 1599.98 1544.88 1700000 1699.98 1644088 1800000 1799.98 1744088 1900.00 1899.97 1844.87 0 23 S 79 7 E 0 19 S 31 27 E 0 Z S 39 13 E 0 13 S 21' 34 E 0 19 S 42 52 bi 0 18 S 44 57 bi 0 19 S 21 49 E 0 24 S 10 7 E 0 21 S 9 37 bi 0 10 S 17 42 ki ZO00. O0 1999.97 1944087 2100000 Z099.97 Z044.87 2200.00 2199.97 2144.87 2300000 2299097 2244087 2400000 2399096 2344086 2500000 2499.96 2444.86 2600.00 2599.96 2544.86 2700.00 2699.96 2644086 2800.00 2799096 2744086 2900.00 2899.96 2844086 0 10 N 82 13 E 0 24 S 83 37 E I ! N 66 49 E I 4 N 61 39 E I 9 N 64 53 E I 2 S 77 15 E 2 3 S 446 E 3 41 S 14 13 W 5 56 S 18 44 W 8 36 S 19 59 bi 3000.00 2999.96 2944086 3100.00 3099.95 3044085 3200000 3199.95 3144.85 3300000 3299.93 3244083 3400.00 3399.91 3344.81 3500000 3499.89 3444.79 3600.00 3599.86 3544.76 3700.00 3699.74 3644064 3800000 3799.39 3744.29 3900000 3898.58 3843.48 FEET OEG/IO0 FEET FEET FEET DEG #IN 0.00 0.00 0.00 N 0.00 E 0.10 0.17 0.11 S O.OZ E 0.46 O.OZ 0.52 S 0'1'8 E 0.68 0.14 0.85 S 0.51 E 0063 0.12 0.90 S 0.90 E 0.44 0.05 0.76 S loll E 0.33 0.00 0.64 S 1.10 E 0.40 0.14 0.68 S 0.96 E 0068 0.00 0.94 S 0.87 E 1.06 0.16 1.35 S 0.90 E 1.53 0.17 1.90 S 1.13 E 1.93 0.18 2.44 S 1.61 E 2.09 0.15 2.77 S 2.16 E 2.30 0.05 3.10 S 2.58 E 2067 0.14 3°62 S 3.09 E 3oll 0.10 4.20 S 3.54 E 3.41 0.20 4.64 S 4.02 E 3054 0045 4.89 S 4.43 E 3.15 1.07 4065 S 5.03 E 2087 0.00 4064 S 6.03 E 2.71 0.16 4.71 S 2.81 0.70 4.96 S 2.93 0.00 5.10 S 3.05 0.31 5027 S 3.53 0.24 5074 S 4.04 0.00 6.16 S 4044 0.21 6.56 S 5.00 0000 7.19 S 5.66 0032 7087 S 6.11 0.42 8.32 S '0.00 : # 0 "0 E 0.11 S 8 25 E 0.55 S 18 41 E 0.99 S 30 50 E 1.2~ S 44 48 E 1.34 S 55 33 E 1.27 S 59 37 E 1.18 S 54 35 E 1.29 S 42 47 E 1.62 S 33 38 E 2.21 S 30 51 E 2.93 S 33 25 E 3o51 S 37 57 E 4.03 S 39 47 E 4.76 S 40 30 E 5.49 S 40 10 E 6.14 S 40 52 E 6.60 S 42 10 E 6085 S 47 16 E 7.61 S 52 28 E 6.90 E 8.36 S 55 41 E 7.43 E ~ 8.93 S 56 17 E 7.52 E 9.09 S 55 50 E 7063 E 9.27 S 55 23 E 7054 E 9.47 S 52 42 E 7.15 E 9.44 S 49 16 E 7o10 E 7.29 E 7.27 E 7.22 E 9.67 $ 47 17 E 10.24 S 45 24 E ,) 10.71 S 42 45 E 11002 S 40 56 E 6.19 0067 8.44 S 6.13 0007 8053 S 5056 0.02 8.25 S 4.41 0.39 7.52 S 3.09 0.00 6.63 S 2.16 2.12 6o16 S 3.80 1.72 8.16 S 8.62 1.97 12099 S 16.91 2.33 20.90 S 29.48 2.81 32.80 S 7.34 E 7.88 E 9.04 E 10.68 E 12.42 E 14.24 E 15.34 E 14.68 E 12.19 E 8.06 E 11.18 S 41 I E 11.61 S 42 43 E 12.24 S 47 37 E 13.06 S 54 51 E 14.08 S 61 56 E 15.51 S 66 37 E 17.37 S 61 59 E 19060 S 48 30 E 24.19 S 30 15 E 33.77 S 13 48 E COMPUTATION DATE: 07-MAR-90 PAGE ' 2 ' BP EXPLORATION 1-67/T-20 ENDICOTT NORTH SLOPEB ALASKA DATE OF SURVEY: 21-DEC-1989 KELLY BUSHING ELEVATION: 55.10 FT ENGINEER: " MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL'DEVIATZON AZIMUTH DEPTH DEPTH DEPTH 'DEG HIN DEG MIN VERTICAL DOGLEG RECTANGULAR:COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EASTdMEST DISTo ': AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4000000 3997009 3941.99 10 58 S 21 40 il 4100.00 4094.81 4039071 13 29 S 18 58 W 4200000 4191066 4136056 15 19 S 14 55 il 4300000 4287.60 4232050 11 28 ; S 13 4 W 4400000 4382.54 4327044 19 8 S 11 35 M 4500'00 4476045 4421035 .ZO 57 S 11 31 g 4600000 4569031 4514.21 22 41 S 12 30 ii 4700000 4660079 4605.69 24 59 S 13 44 g 4800°00 4750060 4695050 27 11 S 14 46 il 4900.00 4838045 4783035 29 53 S 15 43 ~ 46.54 2.19 48.75 67.64 lo96 68.64 92.51 2.10 92.47 120.69 2000 119.82 152001 1°99 150.48 186029 1.69 184.16 223032 2.25 220.45 263.67 2.43 259.77 307.61 2.54 302.37 355.36 2.99 348,43 1.77 E 48.79 S 2 5 E 5.52 il 68.86 S 4 36 12.67 ii 93.33 S 19047 ii 121.39 S 9 14 26.11 M 152.73 S' 9 51 32.91 ii 187.07 S 10 8 40.61 il 224016 ~S 10 26 49078 ii 264.50 S 10 51M 60.60 ii 308°38 73.22 il 356.04 S 11 52 5000.00 4923.83 4868.73 32 45 5100.00 5006.74 4951064 35 23 5200000 5086064 5031054 38 27 5300000 5163.39 5108.29 41 0 5400000 5238.39 5183.29 41 32 5500.00 5313.37 525802? 41 20 5600000 5388033 5333023 41 26 5700.00 5463.50 5408.40 41 4 5800'00 5538.96 5483.86 40 58 5900.00 5614057 5559.47 40 47 S 16 19 W S 16 41 ii S 16 31 W S 16 29 W S 16 29 W S 16 23 ii $ 16 20 w S 16 10 ii S 15 59 ii S 15 46 ii 407039 2.55 463.28 3.10 523.37 3.11 587.46 1.30 653.58 0.25 719-74 0o13 785.92 0.40 851.87 0 917o47 0.32 982092 0028 398.44 S 87.58 W 407.95 S 12 24 ii 452.03 S 103.48 g 463.72 S 12 54 ii 509.63 S 120.63 ~ 523.72 S 13 19 ii 571.10 S 138.80 ii: 587.73 S 13 40 ii 634052 S 157.57 ii 653'79 S 13 57 g 697.99 S 176.27 M 719'91 'S 14 10 M 761.50 S 194.88 il 786.04 S 14 21 ii 824.82 S 213.35 ~ 851097 S 14 30 M 887.87 S 231051 il 917056 S 14 37 ii 950082 S 249.41 M 982.99 S 14 42 ii 6000.00 5690.39 5635.29 40 35 6100000 5766.55 5711.45 40 14 6200.00 5843.01 5787.91 40 9 6300000 5919.62 5864.52 39 41 6400.00 5996.66 5941.56 39 29 6500.00 6074.01 6018.91 39 16 6600000 6151.58 6096.48 39 1 6700.00 6229.48 6174.38 38 39 6800000 6307.75 6252.65 38 22 6900000 6386.30 6331.20 38 6 S 15 29 ii 1048.12 S 15 9 M 1112.92 S 15 7 # 1177.37 S 14 55 !,1 1241.65 S 14 37 ii 1305.39 S 14 34, M 1368.77 S 14 30 ii 1431.88 S 14 41 il 1494.57 S 14 41 ii 1556.80 S 14 33 ii 1618.69 0.32 0.33 0.27 0.60 0.73 0.71 0.34 0.63 0.40 0.10 1013.62 S 266.97 ~ 1048019 S 14 45 ii 1076.12 S 284.06 ~ 1112.98 S 14 47 Il 1138.35 S 300.85 Ii 1177.43 $ 14 48 ii 1200.43 S 317.54 # 1Z41.71 S 14 49 ii 1262.07 S 333.79 ii 1305.46 S 14 49 il 1323.41 S 349.72 ii 1368.84 S 14 48 ii 1384.51 S 365.55 ~ 1431.96 S 14 47 g 1445.20 S 381.30 ii 1494.66 S 14 47 M 1505041 S 397.06 ii 1556.89 $ 14 47 ii 1565030 S 412.67 ti 1618078 S 14 46 ii 7000000 6465.10 6~10.00 37 52 7100.00 6544001 6488.91 37 58 7200000 6622.97 6567.87 37 41 7300.00 6702.05 6646.95 37 57 7400000 6780.81 6725.71 38 12 7500000 6859.27 6804.17 38 27 7600.00 6937.57 6882047 38 36 Y7000 O0 7015.62 6960.52 38 47 7800000 7093.48 7038038 38 55 7900000 7171.15 7116.05 39 16 S 14 25 ii 1680.25 S 14 24 ii 1741.66 S 14 24 ii 1803.02 S 14 22 ii 1864.21 S 14 26 ii 1925.83 S 14 34 ii 1987.81 S 14 41 ii 2050.01 S 14 37 ii 2112.52 S 14 23 il 2175.27 S 14 17 ii 2238.24 0.17 0.23 0.39 0.27 0.63 0.22 0.34 0.27 0 0079 1624.91 S 428.07 M 1680.35 S 14 46 ii 1684.40 S 443.36 il 1741.77 S 14 45 ii 1743.83 S 458064 M 1803.14 S 14 44 Id 1803.13 S 473.80 il 1864.34 S 14 43 ii 1862.82 S 489.10 ii 1925.96 S 14 43 ii 1922.84 S 504.63 Il 1987095 S 14 42 ii 1983.02 S 520.34 il 2050.16 5 14 42 ii 2043.51 S 536.14 Il 2112.68 S 14 42 ii 2104.27 S 551.85 ii 2175043 S 14 42 ii 2165.30 S 567.42 Il 2238.41 S 14 41 M COMPUTATION DATE: 07-NAR-90 PAGE, 3' BP EXPLORATION 1-67/T-20 Iq PI ENDICOTT NORTH SLOPEr ALASKA ® DATE OF SURVEY:, 21-DEC-1989 KELLY' BUSHING ELEVATION: 55.10 FT ENGINEER: NCBRIDE , INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA 'COURSE HEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG ~IN DEG HIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH:EAST/WEST: DIST. AZIRUTH FEET DEG/IO0 FEET FEET FEET DEG NIN 8000.00 7248.16 7193006 .39 35 8100.00 7325.28 7270.18 39 54 8200.00 7401.70 7346.60 40 4 8300.00 7478012 7423.02 40 28 8400.00 7554.11 7499.01 40 55 8500.00 7629072 7574.62 41 3 8600.00 7704.97 7649.87 41 8 8700.00 7780.38 7725.28 41 4 8800.00 7855.55 7800.45 41 25 8900.00 7930059 7875o49 41 22 S 14 6 bi 2365.66 S 13 52 bi 2430.15 S 13 SO bi 2494.62 S 13 49 ~ 2559.60 S 13 53 W 2625.01 S 14 2 ti 2690.85 S 14 3 bi 2756.52 S 14 13 ti 2888.53 1.44 1.05 0.91 0082 0.98 0052 0.53 0.32 0.29 2227.11 S 583.18 W 2302.20 S 14 2288.86 S 598066 W 2365086 .S 14 39 2351043' S 614.33 bi 2430036 S 2414,.06 S 629.73 Id 2;,94.85 S 14 37 bi 2477.20 S 64,5.18 bi 2559084 S 14 36 2540.75 S 660.81 bi 2625.27 S 14 35 bi 2604-66 S 676'69 id 2691013 S 14 34 2668.37 S 692068 bi 2756.81 2732.35 S 708065 Id 2822.75 S 14 32 Id 2796'46 S 724077 ti 2888.85 S 14 32 Id 9000.00 8005.58 7950.48 41 28 9100.00 8080.43 8025.33 41 37 9200.00 8155.22 8100012 41 35 9300.00 8230.02 8174.92 41 35 9~00.00 8304.69. 8249059 41 48 9500.00 8379.04 8323.94 42 0 9600.00 8453.4,7 8398.37 41 47 9700.00 8528.25 8473.15 41 25 9800.00 8603.55 8548.45 40 54 '9900o00 8679.24 6624.14 4,0 50 S 14 23 ti 2954.67 S 14 32 ti 3020.97 S 14 51 td 3087.35 S 15 13 Id 3153.72 S 15 22 bi 3220.23 S 15 31 kl 3287.11 S 15 41 I~ 3353.89 S 15 44 ti 3420.29 S 15 40 ~ 34,86.09 S 15 12 ti 3551.43 0.36 0.25 0.51 0.37 0.50 0.23 0.52 0.54 0.61 0.92 2860.57 S 741.09 M 2955000 S 14 31 ti 2924.78 S 757.66 ti 3021.32 S 14 31 bi 2989.00 S 774.45 ti 3087.70 S 14 32 W 3053.10 S 791.67 bi 3154.07 S 14 32 Id 3117.25 S 809.21 bi 3220.57 S 14 33 ti 3181.72 S 827.'02 W 3287.45 S 14 34 ~J 3246.05 S 844.97 bi 3354.22 S 14 35 bi 3309.96 S 862.93 bi 3/,20.60 S 14 31' bi 3373.31 S 880.72 bi 3486,39 S 14 38 W 3436.30 S ~:898.14 W 3551073 S 14 39 W 10000.00 8755.11 8700.01 40 27 10100.00 8831.56 8776.46 39 44 10200000 8908.94 8853.84 38 59 10300.00 8986.93 8931.83 38 29 10400.00 9065.77 9010.67 37 14 10500.00 9146.08 9090.98 35 54 10600.00 9227.69 9172.59 34 34 10700000 9310.85 9255.75 32 40 10800000 9395.88 9340.78 30 59 10900.00 9482.24 9427.14 29 37 S 14 59 W 3616.58 S 14 58 W 3681.04 S 15 10 W 3744.38 S 15 22 bi 3806.96 S 15 24 ti 3868.48 S 16 3 bi 3928.05 S 16 50 bi 3985.83 S 17 16 Id 4041.33 S 18 4 bi 4093.91 S 18 33 ti 4144.27 0.52 0°94 0.35 1.05 1.34 1o53 1.19 1.70 lo42 1.34 3499.21 S 915.05 ti 3616.88 S 14 3'9 bi 3561.49 S 931oT0 M 3681.34 S 14 40 W 3622066 S 948.11 W 3744.68 S 14 40 bi 3683.03 S 964.60 bi 3807.25 S 14 41 ti 3742.34 S 980.95 ti 3868.77 S 14 41 M 3799.70 S 997.03 W 3928,33 S 14 42 bi 3855.11 S 1013.46 bi 3986010 S 14 44 bi 3908.20 S 1029.71 W ~041-58 S 14 46 bi ) 3958034 S 1045.68 M 4094.13 S 14 48 W 4006.19 S 10&1.59 Y 4144.46 S 14 50 W ~11000.00 9569.79 9514069 28 20 11100.00 9657.90 9602.80 27 54 11200000 9746.63 9691.53 27 6 11300000 9836.14 9781.04 25 55 11400.00 9926.37 9871.27 25 8 11500.00 10016.87 9961.77 24 59 11600000 10107.65 10052.55 24 41 11700.00 10198073 10143.63 24 15 11800000 10289.94 10234.84 23 44 11900000 10381.94 10326.84 22 44 S 19 17 ti 4192049 S 19 29 ~ 4239.66 S 19 58 M 4285.65 S ZO 43 ti 4330.08 S ZO 31 ti 4372.99 S 21 Z ti 4415.36 S ZO 52 Id 4457.11 S 20 35 bi 4498.20 S 20 38 bi ~539.03 S ZO 22 ti 4578.05 0.54 0.79 0.63 1029 0.21 0.82 0.10 1.95 2.03 0.71 4051.91 S 1077.19 bi 4192065 S 14 53 bi 4096.50 S 1092.94 ti 4239.79. S 14 56 W 4139.92 S 1108.50 bi 4285.76 S 14 59 bi 4181.75 S 1123.92 W 4330.16 S 15 3 bi 4222.08 S 1139.12 M 4373.05 S 15 6 ti 4261.88 S 1154.17 bi 4415.40 S 15 9 bi 4301.05 S 1169.18 W 4457.13 S 15 12 bi 4339.66 S 1183.75 ti 4498.21 S 15 15 ti 4378.04 S 1198.17 Id 4539.04 S 15 18 ti 4414.72 S 1211.98 ti 4578.06 S 15 21 ti COHPUTATZON DATE: 07-NAR-90 PAGE * BP EXPLORATION 1-6T/T-Z0 ENDICOTT NORTH SLOPE~ ALASKA DATE OF SURVEY: 21-DEC-1989 KELLY BUSHING ELEVATION: 55.10 FT ENGINEER: ~CBRIDE INTERPOLATED ¥~LUES FOR EVEN 100 FEET OF #EASURED DEPTH TRUE SUB-SEA COURSE HEASURED VERTICAL VERTICAL DEVIATION 'AZI#UTH DEPTH DEPTH DEPTH 'DEG giN DEG WIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/IdEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG NZN 12000000 10474.49 10419°39 21 45 12100000 10567.36 10512.26" 21 445 12150000 10613.81 1055807121'445 S 20 10 Id 4615.80 S ZO 10 W 44652071 S ZO 10 W 4671.1T 1o4.6 0000 0.O0 4450.27 S 1225o05 14 4615o80 S 15 23 Id 44485'03 S 123T.83 14 46520T1 S 1S 26 Id 4502.442 S 12444-21 Id 4671-17 .S 15 27 Id COMPUTATION DATE: O?-.MAR'90 PAGE' 5' BP EXPLORATION 1-67/T-ZO HP! ENDICOTT NORTH SLOPEr ALASKA DATE~OF SURVEY: Z1-DEC-1989 KELLY BUSHING ELEVATION: 55'10 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 1000 FEET OF REASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZINUTH DEPTH DEPTH DEPTH DEG NIN DEG: VERTICAL/ DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/IdEST OIST, AZIMUTH FEET OEG/IO0 FEET FEET FEET~: DEG 0.00 0.00 -55.10 0 0 1000.00 999.99 944.89' ~ 0 23 ZO00. O0 1999.97 1944.87 0 23 3000.00 2999.96 2944-86 0 10 4000°00 3997.09 3941o99 1058 5000.00 4923.83 4868.73 32 45 6000.00 5690.39 5635029 40 35 7000.00 6465.10 6410000 37 52 8000.00 T248.16 7193.06 39 35. 9000.00 8005.58 7950.48 41 28 N 0 0 E 0.00 S 31 30 E 1.53 S T9 7 E 2.71 N 82 13 E 6.19 S 21 40 kl 46.54 S 16 19 Id 407.39 S 15 29 ~ 1048.12 S.14 25 ~ 1680.25 $ 14 14 Id 2302.02 S 14 23 M 2954.67 0.00 0.17 0.16 0 °67 2.19 2.55 0.32 0.17 1.44 0.36 0.00 N 0.00 E 0.00 N 0 0 E lo90 S 1.13 E Z.21 S 30 51 E 4o71 S 6.90 E 8.36 S 55 41 E 8.44 S 7.34 E 11018 S 41 I E 48.75 S 1.77 E ~8.T9 S 2 5 E 39:8.44 S 87.58 ~1 4,07.95 $ 12 24~'~ 1013.62 S 266.97 ~ 1048019 S 14 45 Id ~) 1624.91 S 428.07 ~ 1680.35 S 14 46 Id 2227.11 S 583018 Id 2302.20 S 14 40 Id 2860.57 S 741.09 Id 2955.00 S 14 31 t~ 10000.00 8755.11 8700.01 40 27 11000.00 9569.79 9514.69 28 20 12000.00 104T4.49 10419.39 21 45 12150.00 10613.81 10558.71 21 45 S 14 59 ~ 3616.58 S 19 17 M 4192o49 S 20 10 Id 4615.80 S 20-10 Id 4671.17 0.52 1.46 O*OO 3499.21 S 915.05 W 3616.88 S 14 39 4051.91 S 1077.19 Id 419Z.65 S 14 53 4450.27 S 1225.05 Id 4615.80 S 15 23 W 4502.42 S 1244021 Id 4671.17 S 15 27 COMPUTATION DATE: 07-HAR-90 PAGE* 6' BP EXPLORATION 1-67/T-20 MPI ENDICOTT NORTH SLOPE~ ALASKA DATE OF SURVEY: 21-DEC-1989 KELLY BUSHING ELEVATZON: 5,5o10 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF ,SUB-SEA DEPTH TRUE SUB-SEA COURSE IqEASURED VERTICAL VERT]:CAL DEV]:ATION AZIMUTH DEPTH DEPTH DEPTH DEG NIN DEG MIN 0.00 0o00 -55010 0 0 55.10 55010 :0000 0 0 155.10: 155.10 100000 0 16 255010 255010 ~ 200o00 0 16 355010 355010 300000 0 14 455010 455010 400000 0 9 555010 555010 500000 0 4 655010 655.10 600000 0 6 755010 755010 700000 0 10 855.10 855010 800.00 0 14 0 21 0 26 0 22 0 18 0 26 0 25 0 23 0 17 0 23 0 35 ENGINEER: mCBRIDE 955011 955010 900.00 1055.11 1055010 1000.00 1155.11 1155010 1100000 1255.11 1255.10 1200.00 1355.11 1355.10 1300o00 1455.12 1455010 1400.00 1555.12 1555.10 1500.00 1655.12 1655010 1600.00 1755.12 1755.10 1700000 1855.13 1855010 1800.00 0 31 0 20 0 Z 0 7 0 20 0 20 0 14 0 23 0 24 0 16 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/IdEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG NIN 1955013 1955.10 1900000 2055.13 2055010 2000.00 2155.13 2155 10 2100 00 22 55 I 2200 2z55.]: : o :oo z: 55.:]3 2355.].o z: oo.oo 2,,55. o 24,00.00 2555.14 2555.10 2500.00 Z655o14 2655010 2600.00 2755.14 2755.10 2700000 2855014 2855.10 2800.00 0 6 0 21 0 45 I 1 I 8 I 5 I 24 2 50 4 51 7 23 N 0 0 E 0o 00 0.00 N 0 0 E 0.00 0.00 S 23 39 E 0.31 0.00 S 45 56 E 0.61 0.08 S 85 51 E 0.69 0o14 N 49 47,E 0.53 0o16 N 13 6 id 0036 0009 S 72 23 id 0034 0.03 S 14 30 Id 0054 0.00 S 3 31 E O.8T 0.16 2955014 2955.10 2900.00 3055.14 3055.10 3000.00 3155.15 3155o10 3100000 3255.16 3255010 3200000 3355.18 3355010 3300.00 3455020 3455.10 3400000 3555.22 3555o10 3500000 3655.29 3655010 3600..00 3755051 3755010 3700.00 3856.09 3855010 3800.00 S 23 16 E .1.32 0o18 S 41 24 E lo77 0034 S 64 7 E 2003 0o01 S 52 9 E 2020 0°05 46 4 E 2.47 0.42 37 31 E 2.92 0.00 S 48 21 E 3029 0o17 S 57 34 E 3.51 0.07 N 58 59 E 3.39 0028 S 88 15 E 2.97 0.00 S 84 38 E 2.76 0027 S 66 11 E 2.71 0o19 N 17 36 E 2092 0.25 S 37 ZZ E 2.97 0o14 S 12 47 M 3.30 0.66 S 42 47 id 3082 0.00 S I 41 E 4,026 0059 S 16 49 E 4.73 0.14 S 4 16 id 5.36 0.35 S 4 6 id 5.94 0o01 S 57 23 E 6020 0oll S 77 6 E 6.11r 0.37 N 76 58 E 5.98 1.94 N 66 39 E 4.95 0.06 N 63 18 E 3.68 0.14 N 74 4 E 2.43 0.54 S 27 21 E 2.64 2o12 S 8 ;,3 id 6.09 1o93 S 17 59 Id 12.72 2.40 S 19 0 I11 23037 2.98 0000 N 0.00 E 0000 N 0 0 E 0000 N 0-00 E 0.00 :-N 0 0 E 0034 S 0.08 E 0.35 S 13 I E 0.72 S : 0.34 E 0080 S 24 57 E 0.92 S 0.73 E lo17 S 38 32 E 0.83 S 1.05 E 1.34 S 51 27 E 0068 S 1.12 E lo31 S 58 40 E 0063 S lo03 E 1.21 S 58 21:E 0o81 S 0090 E lo21 S 4,8 7 E lo14 S 0.86 E lo43 S 37 4 E 1.64 S 1.00 E 2.21 S 1.37 E 2064 S lo93 E 2.94 S 2.39 E 3.35 S 2.85 E 3.95 S 3.35 E 4.46 S 3.79 E 4.81 S 4.25 E 4.81 S 4.70 E 4.62 S 5.59 E 1.92 S 31 19 E 2.60 S 31 40 E 3.26 S 36 10 E 3.79 S 39 5 E 4.39 S 40 25 E 5.18 S 40 18 E 5.86 S 40 23 E 6042 S 41 29 E 6073 S 44 18 E 7.25 S 50 25 E 4066 S 6.55 E 4o81 S 7.24 E 5.09 S 7.52 E 5o16 S 7.56 E 5053 S 7.66 E 5.98 S 7032 E 6.35 S 7004 E 6.89 S 7,22 E 7.58 S 7.32 E 8.15 S 7.25 E 8.43 S 7.25 E 8048 S 7.58 E 8.51 S 8.36 E 7087 S 9.94 E 7.02 S 11.61 E 6.22 S 13.43 E 6087 S 15.02 E 10.50 S 15'20 E 16.91 S 13.52 E 27.02 S 10.10 E 8.04 S 54.34 E 8.69 S 56 25 E 9.08 S 55 53 E 9.16 S 55 41 E 9.4*5 S 54 11 E 9.45 S 50 46 E 9049 S 47 57 E 9098 S 46 20 E 10054 S 44 I E 10.91 S 41 38 E 11012 S 40 42 E 11.38 S 41 47 E 11.93 S 44 30 E 12.68 S 51 39 E 13057 S 58 52 E 14.80 S 65 10 E 16.52 S 65 25 E 18.47 S 55 22 E 21065 S 38 38 E 28.84 S ZO 30 E CO#PUTATION DATE: 07-HAR-90 PAGE * BP EXPLORATION 1-67/T-201HP! ENDICOTT NORTH SLOPED ALASKA DATE OF'SURVEY: 21-DEC-1989 KELLY BUSHING ELEYATZON: 55.10 FT ENG]:NEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA"DEPTH TRUE SU6-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZINUTH DEPTH DEPTH DEPTH DEG #IN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HOR[Z. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST° AZI#UTH FEET OEG/IO0 FEET FEET FEET DEG NIH 3957.29 3955.10 3900.00 10 T 6059'25 4055.10 4000000 12 31 4162.15 4155.10 4100.00 14 36 4266°00 4255.10 4200000 16 44 4371o00 4355"10 4300000 18 37 4477.17: 4455.10 4400000 20~34 4584.6! 4555.10 4500~00 22 4693074 4655010 4600000 :24 50 4805.07 4755.10 4700000 27 19 4919.23 4855.10 4800.00 30 28 S 22 Z M 38077 S 19 48 Id 58053 S 16 4 Id 82.73 S 13 42 Id 110.71 S 11 53 Id 142.66 S 11 23 Id 178.22 S 12 19 Id '217041 S 13 40 ti 261005 $ 14 50 Id 309.95 S 15 50 Id 364.99 2.10 2.76 2.03 Z.37 lo66 1.64 2.11 2.38 2.61 3.19 41.50 S 4.69 E 41076 S 6 ZT E 60.02 S 2.48 Id 60.07 S 2 22 bi 83.04 S 10.07 Id 83,66 S 6 55 Id 110.10 S 17.16 Id 111L43 S 8 51 Id 161.30 S : 24.20 Id 1¢3.36 S 9 43 M 176.23 S 31.30 ti 178099 S 10 4 kl 214.67 S 39033 Id 218024 S 10 23 # ) 257.23 S 49017 Id 261.88 S 10 49 Id ' 304.63 S 61.20 Id 310.72 S 11 22 Id 351'.69 S 75.83 Id 365,.64 S 11 58 Id 5037.35 4955.10 49'00.00 33 40 5160.02 5055.10 S'O00.O0 37 14 5289.03 5155.10 5100000 40 SO 5422.31 5255010 5200.00 41 30 5555.64 5355010 5300000 41 30 5668.85 5455.10 5400.00 41 7 5821.37 5555.10 5500000 40 56 5953.49 5655.10 5600.00 40 42 6084.99 5755o10 5700.00 40 17 6215.81 5855.10 5800.00 40 10 S 16 30 M 427082' S 16 34 bi 498.82 S 16 29 Id 580028 S 16 27 Id 668.37 S 16 19 bi 756.53 S 16 12 Id 844.54 S 15 56 bi 931.48 S 15 37 bi 1017.83 S 15 11 ti 1103'23 S 15 T Id 1187.57 2.41 2.97 1.63 0.23 0066 0.60 0.25 0.34 000! 0.21 418,.04 S 93.34 Id 428.33 S 12 35 486.09 S 113065 564022 S 136.76 Id 580.55 S 13 38 Id 648.T0 S 161o76 733.30 S 186.62 Id 756.67 S 14 17 Id 817078 S 211.30 bi 844.64 S 14 29 M 901.34 S 235.36 Id 931.56 S 14 38 M 984.44 S 258.85 M 1017090 S 16 44 M 1066077 S 281.53 Id 1103029 S 14 47 M 1148.20 S 303.5! Id 1187.63 S 14 48 M 6346.08 5955.10 5900.00 39 37 6475057 6055.10 6000.00 39 19 6604.54 6155010 '6100000 39 1 6732.78 6255°10 6200000 38 30 6860.32 6355.10 6300000 38 13 6987.33 6455.10 6400000 37 53 7114006 6555010 6500. O0 37 57 7240058 6655.10 6600.00 37 38 7367032 6755.10 6700000 38 3 7494067 6855.10 6800000 38 26 4 48 Id 1271.05 4 33 Id 1353.30 S 14 30 Id 1434.73 S 14 40 ti 1515.01 5 14 36 Id 1594.18 S 14 Z6 ti 1672.47 S 14 25 Id 1750.31 S 14 20 ti 1827.80 S 14 23 M 1905065 S 14 34 Id 1984.50 0.18 0.44 0.36 0.29 0.28 0.24 0.19 0.62 0.26 0.27 1228.84 S 325.08 Id 1271.11 S 14 49 1308.44 S 345.83 Imf1353.37 S 14 48 Id 1387.28 S 366.26 ti 1434.81 S 14 47 M 1464.98 S 386.47 bi 1515010 S 14 47 1541.57 S 406.50 U 1594*27 S 14 46'id 1617.37 S 426.13 ti 1672.57 S 14 46 Id 1692077 S 445051 bi 1750.4Z S 14 45 1767.85 S 464.79 bi 1827.93 S 14 44 Id 1843.28 S 484.08 Id 1905.79 S 14 43 Id 1919063 S 503.80 Id 1984.64 S 14 42 Id 7622.43 6955.10 6900.00 38 38 7750066 7055.10 TO00.O0 38 53 7879.29 7155.10 7100.00 39 6 8009000 7255.10 7200000 39 31 8138.99 7355.10 7300.00 40 17 8269.78 7455.10 T40O.O0 40 18 8401031 7555.10 T50O.O0 40 55 8533.71 7655.10 7600.00 41 15 8666048 7755.10 7700.00 41 3 8799.40 7855.10 7800000 41 25 S 14 39 Id 2064001 S 14 31 Id 2144.27 S 14 18 ti 2225.15 S 14 11 Id 2307074 S 14 8 Id 2390077 S 13 50 ti 2475004 S 13 49 Id 2560.46 S 13 57 bi 2647.19 S 14 9 ti 2734051 S 14 ¢ Id 2822004 0.02 0.68 0.48 1.17 0.83 1.19 0.80 0.61 0.27 0.33 1996.57 S 523.88 Id 2064015 S 14 42 Id 2074025 S 544.12 Id 2164043 S 14 42 M 2152.62 S 564.19 tt 2225.32 S 14 41 Id 2232.66 S 586.58 Id 2307.93 S 14 40 Id 2313.22 S 604.79 ti 2390097 S 14 39 M 2395.04 S 625.05 Id 2475.26 S 14 38 Id 2478.04 S 645.38 Id 2560070 S 14 36 Id 2562.29 S 666.15 ti 2647.46 S 14 34 Id 2647002 S 687.32 Id 2734.80 S 14 33 ti 2731.97 S 708056 Id 2822.35 S 14 32 M COMPUTATION DATE: O7-MAR-90 PAGE ' 8 * BP EXPLORATION 1-67/T-20 ENDICOTT NORTH SLOPE, ALASKA DATE OF SURVEY: :21-DEC-1989 KELLY BUSHING ELEVATION: 55.10 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZINUTH DEPTH DEPTH DEPTH DEG HIN DEG VERTXCAL DOGLEG RECTANGULAR COOROINATES HORIZ. DEPARTURE SECTXDN SEVERITY NORTH/SOUTH EAST/biEST OZST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG #XN 8932.66 7955.10 7900.00. 61 22 9066014 8055.10 8000.00 ~41 33 9199.84 8155.10 8100.00 ~41 35 9333.56 8255.10 8200.00 41 41 9667.78 8355.10 8300.00 62 3 9602.19 8455010 8400.00 41 46 9735.76 8555010 8500.00 41 13 9868.11 8655.10 8600000 60 47 9999.99 8755.10 8700.000 40 27 10130.56 8855.10 8800.00 39 27 10259.26 8955.10 8900.00 38 41 10386.58 9055.10 9000000 37 27 10511.12 9155.10 9100.00 35 47 10633019 9255.10 9200000 34 6 10752.27 9355.10 9300000 31 40 10868°73 9455.10 9400.00 30 2 10983.31 9555.10 9500000 28 21 11096083 9655010 9600.00 27 55 11209.51 9755.10 9700.00 27 1 1'1321.07 9855.10 9800000 25 44 11431.75 995'5.10 9900.00 25 15 11542.16 10055.10 10000.00 24 51 11652.16 10155010 10100.00 24 ZO 11761087 10255.10 10200.00 24 10 11870.89 10355.10 10300000 22 52 11979.12 10455.10 10400.00 21 56 12086080 10555.10 10500.00 21 45 12150.00 10613.81 10558071 21 45 S 14 16 bi 2910011 S 14 31 bi 2998050 S 14 51 bi 3087.25 S 15 16 bi 3176.01 S 15 29 bi 3265.54 S 15 41 g 3355.35 S 15 41 bi 3443.90 S 15 24 g 3530059 14 59 W 3616.57 14 59 bi 3700o51 S 15 20 bi 3781.54 S 15 24 bi 3860.34 S 16 11 bi 3934.56 S 16 57 bi 4004.53 S 17 43 bi 4069.14 S 18 25 bi 4128.75 S 19 12 bi 4184.58 S 19 28 bi 4Z38.18 S 20 I W 4289.97 S 20 46 W 4339.21 S 20 35 ~ 4386.45 S ZO 57 ~ 4433.04 S ZO 37 bi 4478.67 S ZO 36 bi 4523.60 S 20 41 bi 4566.82 S 20 7 bi 4608.06 S 20 10 ~ 4647.83 S 20 10 bi 4671.17 0.33 0.24 0.51 0o21 0.08 0.57 0.89 0046 0.52 0.82 0.02 lo95 1.40 1.55 1.88 1.39 0.87 0.73 0.89 0.68 0.57 1.21 0.48 0.71 0.76 lo20 0.00 0.00 2817.38 S 730.08 bi 2910.44 S 14 32 bi 290~.02 S 752.03 bi 2'998.84 S 14 31 bi 2988.90 S 774042 bi '3087.60 S 14 32 H 3074.61 S 797.53 bi 3176.36 S 14 33 ~i 3160093 S 821.26 bi 3265.88 S 14 34 bi 3247.45 S 845.36 ~d 335'5068 S 14 35 bi 3332.70 S 869.32 bi 3444.21 S 14 37 ~ ) 3416.19 S 892.65 bi 3530.89 S 14 39 bi 3499.20 S 915.05 bi 3616.87 S 14 39 bi 3580030 S 936.73 bi 3700.81 S 14 40 bi 3658052 S 957.88 bi 3781.84 S 14 40 ~ 3734.49 S 978.79 bi 3860.63 S 14 41 bi 3805.95 S 998.84 bi 3934.84 S 14 42 bi 3873.00 S 1018.90 'M 4004*79 S 14 44 bi 3934074 S 1038.08 bi 4069037 S 14 47 bi 3991.45 S 1056.67 bi 4128.95 S 14 50 bi 4044.42 S 1074.58 bi 4184.74 S 14 53 # 4095.10 S 1092.45 bi 4238.31 S 14 56 bi 4143.99 S 1109.97 W 4290.07 S 15 0 bi 4190.33 S 1127017 ~ 4339.28 S 15 3 bi 4234.74 S 1143.86 bi 4386.50 S 15 7 bi 4278.46 S 1160.56 bi 4433.07 S 15 11 bi 4321.31 S 1176.83 bi 4478.69 S 15 14 bi 4363.53 S 1192.72 bi 4523.61 S 15 17 bi 4404.15 S 1208.02 id 4566082 S 15 20 bi 4442.98 S 1222.38 bi 4608.06 S 15 23 bi 4480.44 S 1236014 bi 4647083 S 15 25 bi 4502042 S 1244.21 bi 4671.17 S 15 27 bi COMPUTATION DATE: O7-MAR-90 PAGE' BP'EXPLORATION 1-67/T-ZO.MP! ENDICOTT NORTH SLOPEr ALASKA MARKER GCT LAST READING PBTD DRZLLEReS DEPTH DATE OF SURVEY: 21-DEC-1989 KELLY BUSHING'ELEVATION: 55o10 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE, LOCATION = 2Z30e SNL ~ Z224~ ~IEL~ SEC36 TIZN R16E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH' 'EAST/WEST 12002°30 10476o61 10421.51 1Z050°00 105ZO°BZ 10465.82 12150°00 10613°81 10558o71 4451o05 S 1225.36.W 4467.64 S 1231.45 ~ 450Z.42 S 1244.21 ~ COMPUTATION DATE: 07-MAR-90 PAGE' 10' BP EXPLORATION 1-67/T'ZO ENDICOTT NORTH SLOPEr ALASKA MARKER PBTD DRILLER tS DEPTH ************ STRATIGRAPHIC SURFACE #EASUREO DEPTH BELOkl KB 1Z050.00 1Z150o00 KELLY SUMHARY *********$** LOCATION = 2230" SNL TVD FROM KB SUB-SEA 10520o9Z 10465o8Z 10613.81 10558o7! DATE OF SURVEY: 21-DEC-1989 BUSHING ELEVATIOM: 55o10 FT EBGINEER: MCBRIDE 222.4' NELt. SEC36 T12N R16E RECTANGULAR COORDINATES NORTH/SOUTH' ' EAST/gEST 4467°64 S 1231o45 ~J 450Z.42 S 12~.21 g FZNAL MEASURED DEPTH ~ELL LOCATION AT TO: TRUE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH 12150°00 10613°81 10558o71 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 4671°17 S 15 27 W SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY BP EXPLORATION WELL i-67/T-20 MP I FIELO ENO I COTT COUNTRY USA RUN ONE DATE LOOOED 2i - DEC - 89 REFERENCE 73712 ,WELL' (2230' 1-67/T-20 MPI ~ SNL, 2224' WEL, SL,~ 36, T12N, R16E) HORIZONTAL PROJECTION NC~TH 2000 ! 000 -2OOO -3OOO -4000 -SO00 SOIJTH -S000 HEST REF 73712 SCALE : 1/1000 IN/FT .-t--.4.*.4.--J..-.~.---i.-.**--4-.-b.. .4...q-....I... '..' .' ' ' ~ ............ 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LLL4 ...... ~..~...~..-~..-.4...LL~ ....... ~.--b..b.b~..-b.-~..4..-~ ...... b~..4..-~ ....... ~.--b-.L-b...'.~..-b-b4..~.-~.--b~....~ ...... b4..-b4 ...... b+.4..-b~..4..-L-L-~ ....... b.b4.4 ...... b~..L-~ ...... ~....~.4,...~..~ .-4..4-+-~-- 4-4-~-~-~-~-~-.~.-4-- -~-4-4-~"-.--b4..4.-~ ......4 b4---b-~ .... b-b--b-h-..-~.-¥-4--~ ....... b+.4.--b4.-~.--b-b4 ...... b+--b.~ ...... b-b+.-b-b--b-b4..~ ...... b+-~.--b- ..H¥.-k..~ ..... b..b4..-b. · '."fi'ff" ,-" kff"ff-'?l"-r+"f--~ ....... ~-'~"-k'-~ ...... k?-k'-?'-"i--?'-~ ..... k-?'-r'-~ ....... r--r--?r ..... ~'-r'~--r'F-r--r-?~ ..... ?T'T'" ..... ~--r'-r'~ ....... r'-~'T"~ ....... ?'?"T'~"'~"~-T"? ....... ?'T"?T"~ 6000 19S. PROJECTION ON VERTICAL PLANE 19S. - IS. ~CALEO IN VERTICP~. OEP~H~ HORIZ SCALE = 1/1000 IN/FT BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 January 15, 1990 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 1-45/Q-26 ~rFORMATION MULTI- TESTER 13305'-13310' Run No. 1 ATLAS WlRELINE SERVICES ¢,/DUAL LATEROLOG 13172' - 14282" Run No. 1 ATLAS WIRELINE SERVICES ~'~rZ- DENSILOG COMPENSATED NEUTRON GAMMA RAY 13172' - 14263' 'Run No. '1 ATLAS WIRELINE SERVICES , /~_ELL 1-67/T-20 ~,/*~'~'L'i~~ON SHORTGUARD LOG 2470' - 10961' .. Run No. 1 HALLIBURTON ~'ULL WAVE SONIC R E C E IV re..: I) 2460' - 10925' Run No. 1 HALLIBURTON JAN 1 6 !990 ~-~*'"~UE VERTICAL DEPTH LOG (DIL/GR) Alaska 011 & Gas Cons. Anchorage 10956' - 12090' Run No. 1 SCHLUMBERGER ' ~UAL INDUCTION - SFL 10956' - 12090' Run No. 1 . ~HLUMBERGER ~ *REPEAT FORMATION TESTER 11330' - 11722' Run No.1 _ .~HLUMBERGER ~/*SPECTRAL DENSITY DUAL SPACED NEUTRON LOG 2470'- 10961' Run No. 1 HALLIBURTON .~OMPLETION RECORD PACKER 11490' - 11800' Run No. 4 SCHLUMBERGER ~CCEMENT EVALUATION LOG (CET) 10510' - 12035' Run No. 1 LUMBERGER · ~EMENT BOND LOG (CBT) 10510"- 12035' Run No. 1 SCHLUMBERGER WELL 1-05/O-20 *INJECTION PROFILE SURVEY 10100' - 11117 Run No. 1 CAMCO t/,/WELL 3-05/O-29 *PRODUCTION PROFILE LOG 11750' - 12270" Run No. 1 CAMCO .sELL3-33/K~,37 · PINNER TEMPERATURE 13100' - N/A · HRS , .~, ELL 3-47/0-35 *PERFORATING RECORD : 9990' - 10500' Run No. 1 SCHLUMBERGER RECEIVED **pELL 4-46/N-39 RODUCTION LOGGING SERVICES 11600' - 12000' Run No. 1 Ap~RESS WlRELINE SERVICES SURE DATA GRADIENT/PBU HP/TEMPERATURE 11650' - 11750' Run No. 1 ATLAS WlRELINE SERVICES JAN 16 Alaska 011 &' (~as Cons. Commission Anchorage October 31, 1989 Telecopy: (907)276-7542 M. E. Miller Endicott Lead Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Duck Island Unit/Endicott 1-67/T-20 M_PI BP Exploration (Alaska) Inc. Permit No. 89-1t4 Sur. Loc. 2230'SNL, 2224'WEL, Sec. 36, T12N, R16E, UM. Btmhole Loc. i528'SNL, 3714'WEL, Sec. 1, TllN, R16E, UM. Dear Mr. Miller 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 pe~itting 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 Co_m~_ission 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 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF ~E COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill I-Illb. Type of well. Exploratory l-I Stratigraphic Test l-I Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Nd'me of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Fie/d/Endicott Pool 3. Address 6. Property Designation P. 0. Box 196612, Anchora(Te,Alaska 99519-6612 ADL 34636 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 2230' SNL, 2224' WEL, Sec. 36, T12N, R16 Duck Island Unit/Endicott At top of productive interval 8. Well number Number 1200' SNL, 3600' WEL, Sec. 1, T11N, R16E 1-67/7'-20 MPI 2S100302630-277 At total depth 9. Approximate spud date Amount 1528' SNL, 3714' WEL, Sec. 1, T11N, R16E November 7, 1989 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(aoandTVD) prop~L line 47502 @ 1565' feet 1-63/T-22 @ 14feet 2560 12,113' MD/10,506' TVDfeet il 6. To be completed for deviated wells 17. Anticipated pressure (see 20 ^^c 25.o3s (e)(2)) Kickott depth 3500 feet Maximum hole angle 37.9* Uax~rnum 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" Drive 75' Surfacel 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 9514' Surface 9570' 8500' 12-1/4" 9-5/8" 47# ~v?gsHs NSCC 1338 9570 8500' 10908' 9556' 525 cu ft. Class G 8-1/2" 7" 29# HT95~S TKC 1455 10658' 9359' 12113' 10506' 465 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 RECEIVED Surface Intermediate 0C'T Production Liner &lasJ(a .Oi! & Gas Cons, C0mmJssj~il Perforation depth: measured ~'-J .... ~,nch0rage ,;~ ' .... 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 requirementsl-I 21. I hereby certify that the fo,,~ correct to the best of my knowledge Signed./~" ~ Z Y ~1,~ Title Endicott Lead Engineer Date ~Commission Use Only J Permit Number IAPI number IApproval date ISee cover letter ~ ?~//~/ I5 o- o ~_ ? - ~ / ? J~.5' I :~ 0 / 31 / 8 9 Ifor other requirements Conditibns of al~proval Samples required [] Yes ~[~['NO Mud log required I-lYes .I~'NO Hydrogen sulfide measures [] Yes ~ No Directional. survey requ~recl ,~Yes [] No Required working/Fl~ure~for Bj;~'~/A~] 2M; ,~IVI; J;~5U; 17'110U; I-!15M; Other: / /~,"~ /~///,~ .~~~_._.~ by order of ,.._A_p_p_ro~v~ed.~y _~_ _~2,.[_~_ ~- ~ _~t~ Commissioner me commission Dar Form 10-401 R~ 12-1-85 Submit in tri cate PROPOSED DRILLING AND COMPLETION PROGRAM WELL 1-67/T-20 (MPI) Objective Well 1-67/T-20 will be drilled as a water injection well. Zone 3C is the primary objective. The completion will be run at the time of drilling and will consist of a simple type assembly. Operation Execute a rig move to slot 1-67 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. Run 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/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. Complete with a simple 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. Fluids incidental to the drilling of a well will be pumped down the 13-3/8" by 9- 5/8" annulus of the well. Once the rig is released the 13-3/8" x 9-5/8" annulus will be freeze protected with a non-freezing fluid down to 3000 feet, and the well will be perforated with wireline conveyed guns. Note: Notify Alaska Oil and Gas Conservation Commission pri~ testing casing, production liner, liner lap, and performing MIT. ENDICOTT PROPOSED DIAGRAM WELL 1-67/T-20 (MPI) NON-FREEZING FLUID TVD (BKB) MD (BKB) 30" DRIVE PIPE 131 FT 131 FT BASE PERMAFROST 1466 FT 1466 FT SSSV 1550 FT 1550 FT 13-3/8" 68=/FT NT-8OCYHE BTC 2500 FT 2500 FT BOTTOM OF FREEZE PROTECTION (ESTIMATED) 3000 FT KOP(DIR:S 19.1° W; ANGLE: 37.9DEG) 3500 FT 4-1/2", 12.6=/FT L-8OTDSTUB~C~ C E I V ED W/ 4-1/2" TAILPIPE TOP OF 9-5/8" CEMENT (ESTIMATED) 9108 FT 9-5/8"47=/FT NT80S NSCC 8500 FT 9570 FT 4-1/2" SLIDING SLEEVE 9-5/8" PACKER 7" LINER TOP 9319FT 10608 FT 9359 FT 10658 FT 9-5/8" 47=/FT NT95HS NSCC 9556 FT 10908 FT PLUG BACK TD 7" 29=/FT NT-95HS BUTT (TKC) LINER 12033 FT 10506 FT 12113 FT KRL/1 0-8-89 G.O.P. STACK CONFIGURATION 13-5/8 IN. TRIPLE RAP1 STACK 5000 PSI WP DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAilS ,1 I i Z IN. KILL LINE OATE OATE DRILLING SPOOL I ! PIPE RAt'IS · I [ m 4 IN. CHOKE LINE ~ND HYD. ASST. GATE GATE ENDICOTT DEVELOPMENT WELL 1-67/T-20 (MPI) TRUE NORTH GRID SLOT 1-67 SURFACE LOCATION X = 258,974 FT ;Y = 5,982,187 FT 2230 FT SNL; 2224 FT WEL SEC 36, T12N, R16E S 19° 06'W DEPARTURE TO TARGET: 4498 FT 11549 FT MD 10061 FT TVD BKB DEPARTURE TO BHL: 4845 FT 12113 FT MD 10506 FT TVD BKB NOTE: THE NEAREST WELL TO 1-67/T-20 IS 1-63/T-22 LOCATED 20 FT NORTHEAST AT SLOT 1-63. KRL/10-20-89 31 424000 44 0 6a_o 640~J 68660 3G IV 0 TES ' 36 CERTIFICATE _ OF SURVEYOR o I #eorby certify thatl om properly registered and licensed to practice land surveying in the State of Alaskoend that this plat represents an proposed location for tho Well numbers ehown above. All eurvey&ng was done byme or under my supervis~n, and that oil dimens(onl end detail~ ore correct. DRW. 116-85 SHEET 2 of I0 REV. - Indicates well Indicates CalcUlated Section Corner I~oeltion Indicates Perpendicular Offset Ditten¢l Indicates ~endiculer Offset Distance endiculor~istonc~ es for PLAT OF MPI P~OPOS~D I[LL LOCATION~ LOCATED IN IEC.:II, T. IZN.,R. It [. UHIAT Id. PREPAREO FOR SOHIO ALASKA PETROLEUM CO. PR E PAR E D BY F.R. BELL ~ ASSOC.' PRUDHOE BAY OFFICE PRUDHOE BAY, ALASKA I IIII L III II _ DATE' NOV-13, Ills SCALE' I"" DRAWN BY: CHECKED BY' I.E. I V-'~91~41~.37 N-~10~3~4.~X '"~l'l~.Oi~O~ 14~lT'li,illi' lill.il X- 2~9110.7~ E- 464137.36 i, · 2 Y' ~gB2~79,BB N' 780~3~,~2 70°2~'20,9814' 147°57'24,62~7' IB3~,43 Z~6S,94 X' 259041,49 E- 464094.4~ 3 Y= 5982474.18 N= 7805521.98 70~21'09.984&" 147c57'20.6258" 1936.77, 2~32.11 X= 259175,01 E- 464155,65 i 4 Y- ~82~71.S~ N~ 7~05'~50.~ 70°~1'~0.~'-~47:~7'~4.~5S' ~84~.~0 ~1~4.4~ 6 Y~ B~82~63.B0 N' 7~05~4B.47 70~1'10.~16B' 147°B~'24'.~4~4' X" 259030,02 E- 464091,04 7 Y,'59824~7.~0 N-780~3~6.94 70~22'09.8200" 147~:7'20.94::"''' :9:3.':2 204~;0~" x- 2:9:6~.:4 E- 464~32.~4 ~ y. :982~::.~0 N- 780:~4:.94 70~2~'~0.7344" :47o:7'25.~0:3' ~,60.:4 X" 259024,29 E- 464089,33 9 Y= ~9B2449,61 N= 7805314,41 70021'09,7376- 1470~7'21,1054" 1961,19 204B,53 X- 259157,80 E- 464130,53 10 Y- 59~2547,11 N- 7B05343,42 70~21'10.6521" 147~'2~,26~1" 1BBB,91 2190,B3 X- 2~9018,~ E- 464087,62 11 Y- 5982441.42 N- 7805311.B9 70t21'09,6~5~~ 147°57'21,265~" 1970,26 20~4,00 X- 259152,07 E- 464128,B3 12 Y- ~9B2~38.92 H- 7805340.90 70~21'10,~697" 147°57'2'~.42~0" IB77,2B 219~'30 X- 259012,82 E- 464085.92 13 Y- ~982433,'23 N- 7805309.36 70~21'09.5730" 1"'47°~7'21,4~1"" 1978.63.. 2059,47 x- 2:9~46.33 E- 464~27.t2 "' 14 Y- ~982~30.73 N- 7~0~338,37 70~21'10,4874· 147°~7'2~,~B49· 18~,'66 220"1,77 x- 2:~007,0~ E- 464084,~1 1~ Y- ~98242~.03 N- 780~306,B4 70~ 21' 09. 4906· 147c57'2i,58~0· 1987,00 2064,94 X- 259140,60 E- 464125,42 16 Y- ~982~22,54 N-"'780533~,~5 70~21'10,4051" 147°~7'2~,744~" 1194,0~-~207,24 X- 2~9001,3~ E- 464082,50 i7 Y- :gB24i6.B4' N- 780~04.3~ 70o2~'09.40~3· ~47~7'21.7449· 199~.3~ 2070.41 X- 2:9t34.~6 E- 464t23.71 18 Y" 5982514,35 N- 7B05333,32 70°21'10.3227" 147°~7'2'5,904&" 1'902,'40 2212,71 X- 2~899~,61 E- 464080,80 :9 Y- :982408.6~ ~- 780:~0~.79 7~21'0~.3260" ~47o:7'2:.9047"" 200'3.7~207:.,9 X= 259129.13 E= 464122,00 20 Y= ~982506.16 N= 7805330.80 70~21'~0,2404~ "'j*'47~7'26,0644''' 1910,77 2218,18 X= 2~8989.87 E= 464079.09 21 Y= ~982400,46 N= 7805299.27 70021'09,2436· 147e~7'22,0&4&' 2012,12' 2081.36 X= 2~9123,39 E= 464120,30 ..... i i~ i ii i ~ i MPI PRO~SED WELL L~ATION LIST ~¢ OF.AL,~t__ LOCATED IN SEC. 3S,T. 12N.,R.ISE. UMIAT M. · "~--~~'~ ~ SOHIO ALASKA PETROLEUM CO. fa"~% ~691~ '~ DRW. NO. 116-85 PREPARED BY DATE'NOV. 13, 1~85 '.~a~,-.,~~-- F.R. BELL & ASSOC ~oF_ ;;;~k~~ SHE ET ~ of I0 · SCALE · ~~~ PRUDHOE BAY OFFICE O~,WN BY: RG.~ ~[v. o PRUOHOE BAY~ ALASKA CHECKED BY: B.E. i ~m , m m m I I ii I I I I 22 Y- S~12497.t7 N"'7i05321.27 7~i~lO, l~ll· 14~B7'21,2243' lilt. IS X- 251914,~4 E- 4~4077.31 ~ 23 .... Y- 59B2392.27 N- 7BO529&,74 70~2J'O~"t~13" 147~7'22.224'4· 2020.~ 20B~,13 X- 2~9t~7,6~ E" 464rrB.S9 ..~ 24 ,Y- ~48q.77 N' 7805325.75 :70~21'10,07~7· 147c~7'26,3842" 1927.~3 2229,13 X= 258978 40 ' E= 464075 68 25 Y- 5982-~4.08 N=' 7805294,22':7'0~21;09.0790" i 147: 57'22,5B45" 2028.8b 2092,50 ~X' 259[tl,92 [_E' 464116,B8 ~.. 26 :Y= ~~B24B~,~B ~N= 7B0~2~.2~ 70~ 22 09,99~4 ~47c~7 26.~440 . ~9~.90 22~4.60 X- 2~8972 67 ~ E= 46407~ 97 . 27 '~Y- ~982~7~:B~'N- 78o~2~:6~ 70~2~'0B.'~66" ~47~'~7'22.~442" ~ 2037.24'2097.77 2B Y- ~982473,39 N- 7B0~320.70 70o2t.09,~ttl, 1470~7'26,7039· l~d4.27 2240,07 X- 2~8966.93 E- 464072.27 29 Y- ~982367,70 N- 7B0~289,~7 70021.0B,9~43, 147~ 57 ' 22, 7040" 204~,~.. 2t03.24 X" 259100.45 E" 4641t3.47 30 Y" ~982465.20 N' 7BO~31B.tB 70c21'09.12B7" 147o57'2&.B&37" 1932.&4 2'2~5.54 X' 2~8961.20 E" 464070 56 ~ 31 Y" ~982359.~0 N' 780~286:*~ 70~2~'08.B320" ~47c~7'22.B&39· 2~';~i 2~01.72 X- 2~9094.7~ E- 46411t~76 32 Y- 59B24~7.01 N, 7805315 &5 70~ 21' 09. 74&4· J47c~7'27.0236· 19&1.01 X- 2589~5.46 Em 46406B 8~ j 3~ Y'- ~9823~1.31 ~47c~7'23.0237" 2062.3~ N- 7805284 12 ]70~21'08.7496" X- 2~9088.98 E- 464tt0~06 i ' 34 Y' 5962448.82 N' 76053t3 t3 70c2t'09.6641" 147o57'27.1634" t9~9,39 2256.49 X' 258949.73 E' 464067 5962316.55 N' 7605274.02 70021'09.4203, 147°57'23.6632' ~ 20~.64 2'~36.07 y- X' 259066.03 E' 464~03.23 I 36 Y' 5962416.05 H' 7605303.03 70021'09.3347. 147C57'27.B229' 2002.~7 2276.37 X~ 256926.76 E- 464060.32 ~ 37 Y- 5982310,36 N- 7605271,50 ~70o21;08.3379' ~47o57'23.B2~0' 2~04.21 21~1.55 X- 259060,30 E~ 464101,53 38 Y- 5992407.66 N- 7605300.51 70021'09.2524· 147o57'27.9B27' 201~.24 2263.84 X- 25692~.05 E- 464058.6~ 39 Y- 5962302.17 N- 7605266.96 70021.0B.2556, t47~57'23.9129· 2tt2.Sg 2t47.02 X- 2~90~4.~6 E- 464099.B2 40 Y- ~982399.~7 N- 780~297 98 ~70~21'09.1700" ~47~57'2B.1426· 20~9.~2 2289.31 X- 2~B9t~,3t E- 4640~6:9~ 41 Y- 5982293.97 N- 7B0~266.45 70o2~'08.1733" 147~57'24.~427" 2~20.~ 2~52.49 X- 2~904B.83 ~ E- 464098,t~ 4 42 Y- 5982391.4B: N- 7B0529~.46 70021'09.0877" 147~57'2B.3024" 2027.99 2294.79 X- 2~8909.~B ~ E- 4640~.20 . ._ i i i . MPI PR SED WELL L ATION LIST SOHIO ALASKA PETROLEUM CO. 'I:%~E~~~' DRW. NO. 1,6-85 PREPARED BY '~~SS~~~ SHEET 4 of IO F.R. BELL & ASSOC. SCALE: N/A '~%~~ ' " PRUDHOE BAY O~ICE -' REV O PRUDHOE BAY, ~ASKA DRAWN BY~ R.G.~ '- · CHECKED BY: B.E. ii iii i i i IIELL AlP ZOItE I UTk .ONE & LI~TZTUDE kiln .rUlE IIIT{~ lllT{~ 43;-~Y,, S91221,~'71 N, 71052&$.938 70¢'21'01.090~l· i4'~S~'24.$62&' ]13'~t.11 X- -2'~9045.09 E- 464096.4! 44 Y- 5982383'.29 N- 7805292,95"' 70~21'09.00~4'. 147o57'28.4623· 2O$&.$& 2300.26 X,, 258903.B4 E,, 464053.~0 4,5 ~Y'" 5~82277,59 ' N" 7805261,40 70: 21'08.0086' : ~4'-~-'~'~"2'~"~'~'~; 2i37.70 216~.4~ ........ ~i._?:~ ..... _~59037.3b E' 464094.70 4& Y= 5982375.10~ N- 7805290 41 70:21-;C~{~-9230" i 147~-57'2B,622'~'~"i '~{)4'4-:-'~'~ x, 25899~. t t ! E- 464051:79' / 47 Y= 59822~9.40 780'5'~-5~ 88 70c21 07.9263 ~ 147c57 24.6223 x· 25,~0~1,62 E= 4640~2,99 i i 48 ¥= ~82:~b6.91 N= '7B052e7,89 170~21'08.8407" 147°57'28.'7~i20" 205;5.10i2511.20 ..... X= 2588~2.37 E= 464050.08 49 Y= ~82261.21 '~;~'~5256.35 70'~21;'07. 8439- 147°57'24.7S22' ~ -2i~4;44'' 2174.38~ X= 259025.89 E= 464091.29 50 ~- 59e2~58.7~ ~--7e05285,3~ '~0~2~'0e.75~" s~7~57'2~'~g· 206~.~7 X= 25~B86.63 E= ~6~04B.3B 5t Y= 596225~.02' N= 7605253.63 70o21'07.7616* ' 147~57'24.942~i 2162.1t ~ 2179.96 X= 259020.15 E= 46~089.58 / x= 2~e~o.eo ~= ~0~.~7 X= 2590~4.41 E= 464097.89 X= 258875.16 E= 4640~4.96 55 Y= 5~223~.~4 "~'= 7~0524~.7~ 70~2~.07~5~e· 147~57'25.2~t7' 2~'7e'~', 2~90 ~0 x= 25~00~.~ E= 4~0~.t7 57 Y= 598222'9;'44' N= 7805246.26 70o2~'07.5146· 147o57'25.~21~' 21~7.13' 2196.27 x- 25eoo~.e~ E= ~0~.~ ~ ~= ~e~2325. e~-.= 7~0527~.27 70o21',~.4~eo"'-i47~'~z"2e.~i~2.' 20e~.t~ X= 2~8863.&9 E= 464041.55 59 Y- ~'982220.2~ N= 78052k3,73 70~21'07.4323· 147°57'2~.~814' 219&.30 2201.7~ x- 2~8997.2~ E= 4640B2.76 ~0 Y= ~9823~'7,76 N=' ~B05272.~4 70o21'08','~467' 147°'~7~29.7411· 2~03.33 2344.03 x= 2~88~7.96 E= 464039.85 61 ~- 5982212,06 N- 7805242'.~I 70~21'07.3499' 147o57'25.7413· 2204.&7 2207.2~ X= 2~8991,47 E= 46408~.05 62 'y. ~9B2309.57 N,' 7805270.22 '70°21'08','~643, 147o57,29.9009· '211~.7~ 2349.~0 X- 2~88~2.22 E= 464038.14 63 Y= ~982203.87 N''780~238.69 '70°2~:*07.2676- 147~'7'2~.9011~ 22~3'~0~ 2212.&9 X= 2~89B5.74 E- 464079.34 ........ . , . .... i I i i i i i ii i ~~~_., MPI PRO~SED WELL L~TION LIST ~'~ ~ 4C'~1 LOCATED IN ~C. 3&,T. IZN. R. IGE. UUIAT · PR E P&R[O FO R ~ 9 ['~~~~~r'l SOHIO ALASKA PETROLEUM CO. l;?~ .~//-[~~~ DRW. NO. lie- 8~ PREPARED BY ~DATE, ql'~'~'~~-- - F.R BELL & ASSOC ~;'v*~S~~ SHEET 5of IO * ' SCALE' N/A ~%~~~ ... PRUDHOE BAY OFFICE - DRAWN BY : RG.T eEV. O PRUDHOE ~Y, ALAS~ CHECKEO iii i i Li ...... ii ..... : ........... kTLL ~tP ZONE 3 UT, ~lE I~ LATXTUBE LO. ,'UB! BXBT~ tteT~ ' i~ Y" S9i2~0Z,'31" N- 71052&7.1~ 7F21~0'1,1120· X' 2SBB4&,41 E' 4&403&.43 &~ Y' ~98229~.&8 N' 78~236,26 Xm 2~89BO,0G E' 464077.&4 66 ~Y- 5~82293.1B ~ H= 78052~5.17 ~ 70:21'08,0~97" 147'57'30,220~" ' 2128.45 ~ 2~'~" , X' 258840.75 E' 464034.73 ' " 67 Y= 5eO2't~72-4e ~ N= 7805233. ,64%"-'70-~-2~=~i'2t'~2~4 ~47-57 26.2208 ' 222{;'~'~"- . 68 Y= 5V82284.~, M= 7~05262,64 i70=2{'08,0~73 X- 258835.0t , E- 464033.02 "'69 ~Y'x. 5982179258968.~3:30~ N=E. 7B05231:t146407423 70c21"07.0206" ~ 147c57'26.3B07" 22'~8. t7 2229.10 70 Y. SeO2276.B0:N- 780S260.t2 70~2['07.e3S0., t47~ST'30.S'403" 2t4S.te 237t.3e X- 258829.20 E- 46403t.3t . ~ ....... , ~ .. i i i i MPI PRO~SEO WE~ L~ATION LIST ~-~ O~ 4~ ~' LOCATED IN SEC. 36,T. IZN.,R.I~E. UMIAT M. , ...... ~% ~.69l~ / ~ DRW. NO. 116-85 PREPARED BY ~TE' NOV. 13, 1~85 - _ ., q~, ~S,~ON~~ "- PRUDHOE B~YOFFICE -- ~%~~ DRAWN BY' R.G~. R~. o PRUDHOE BAY~ALASKA CHECKED BY: B.E. i ll~ ~ i i i i i ii i i search Radius= 200 For proposed well: Location = W--E S-N TVD(SBS) Top 258974.00 5982187.00 -56.00 Bottom 257238.83 5977663.28 10450.00 Cl,~esh Approach Analysi:3 Da~e: 6-OCT-89 Time: 13:53:38 COURSE LINE 1-67/T-20 [21- 1-11-16] Note: Ail depths in feet Below Kelly Bushing (BKB) WELL IDENT Closest Approach /PROPOSED~ /NEARBY~ CLOSEST TVD DEPART TVD DEPART DISTANCE A000-0000083 MI-33 NO COORDINATE A000-0000119 MI-69 NO COORDINATE A000-0000120 MI-70 NO COORDINATE A029-2064000 MISD10 NO COORDINATE A029-2160500 MI-O20 1600.6 A029-2162500 MI-Q21 2363.9 A029-2164800 MI-Q17 3500 A029-2166900 MI-M25 2800 A029-2167200 MI-O25 1900 A029-2169300 MI-P20 2900 A029-2171300 MI-O23 2000 A029-2172200 MI-N22 900 A029-2174800 MI-P24 500 A029-2175000 MI-Sl4 2201 A029-2176700 MI-R12 600 A029-2178800 MI-R25 3445 A029-2182700 MI-P17 1459 A029-2184100 MI-P21 3100 A029-2184700 MI-P19 3500 A029-2185800 MI-S17 3600 A029-2186400 MI-P26 679 A029-2187300 MI-R23 0 A029-2189900 MI-U15 3200 A029-2190500 POINTS WITHIN SPECIFIED SEARCH WINDOW POINTS WITHIN SPECIFIED SEARCH WINDOW POINTS WITHIN SPECIFIED SEARCH WINDOW PoINTs WITHIN SPECIFIED SEARCH WINDOW 0.0 1599.9 18.3 322.3 0.0 2363.0 101.0 24.5 0.0 3500.5 0 .0 2799.8 ! 0.0 1899.9 0.0 2899.8 0.0 2000.0 0.0 900.0 0.0 499.8 0.0 2200.0 0.0 600.0 0.0 3444.0 0.0 1458.3 0.0 3099.7 0.0 3500.1 2.2 3600.4 0.0 678.0 0.0 0.0 0.0 3199.7 6.6 13.2 15.7 18.4 6.5 1.8 8.4 4.8 0.3 36.1 30 6 11 8 38 6 40 5 18 9 0 0 25 0 166.1 214.7 151.8 211.3 123.1 239.4 146.9 184.9 207.8 44.9 138.6 81.7 273.3 143.2 119.2 50.2 145.9 Vertical /PROPOSED\ TVD DEPART Intersection /NEARBY% TVD DEPART VERTICAL DISTANCE 4010.2 57.8 3331.6 157.1 -677.7 4479.0 219.9 6138.6 318.2 1660.5 [4I-Q 1 !5 500.9 0.0 500.0 SUMMARY The well which comes closest to the proposed well is: A029-2190500 MI-T22 Closest approach distance = KICK OFF for this run = 14.4 feet 3500.0 feet 1.5. ~; 1..3 [ ! . ~ 201.5 Search Radius= 200 7 DEGREE LEAD LINE For proposed well: 1-67/T-20 [21- 1-11-16] Location = W-E S-N TVD(SBS) Top 258974.00 5982187.00 -56.00 Bottom 257803.07 5977485.54 10450.00 Note: All depths in feet Below Kelly Bushing (BKB) Closes;: App,:oach Anal~'~i:~ Date: 6-OCT-89 Time: 13:55:23 Closest Approach WELL IDENT /PROPOSED~ /NEARBY~ CLOSEST TVD DEPART TVD DEPART DISTANCE A000-0000083 MI-33 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW A000-0000119 MI-69 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW A000-0000120 MI-70 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW A029-2064000 MISD10 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW A029-2160500 MI-O20 1600.6 0.0 1599.9 18.3 322.3 A029-2162500 MI-Q21 2363.9 0.0 2363.0 101.0 24.5 A029-2164800 MI-Q17 A029-2166900 MI-M25 A029-2167200 MI-O25 A029-2169300 PlI-P20 A029-2171300 MI-O23 A029-2172200 MI-N22 A029-2174800 MI-P24 A029-2175000 MI-Sl4 A029-2176700 MI-R12 A029-2178800 MI-R25 A029-2182700 MI-P17 A029-2184100 MI-P21 A029-2184700 MI-P19 A029-2185800 MI-S17 A029-2186400 MI-P26 A029-2187300 MI-R23 A029-2189900 MI-U15 A029-2190500 3500 0 2800 7 1900 9 2900 3 200c) 8 900 7 50O 3 2201 0 6O0 9 3445 0 1459 2 3100 7 3500 0 3600 0 679 l 0.9 3200 . ! 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0.0 0.0 0.0 0 0 0 0 0 0 2 2 0 0 0 0 0 0 3'500 5 2799 8 1899 9 2899 8 2000 0 900 0 499 8 2200.0 600.0 3444.0 1458.3 3099.7 3500.1 3600.4 678.0 0.0 3199.7 6.6 13.2 15.7 18 .4 6.5 1.8 8.4 4.8 0.3 36 .1 30 .6 11.8 38.6 40.5 18 .9 0.0 25.0 166.1 214 7 151 8 211 3 123 239 4 146 9 184.9 207.8 44.9 138.6 81.7 273.3 143.5 119.2 50.2 145.9 Vertical /PROPOSED~ TVD DEPART Intersection /NEARBY~ TVD DEPART VERTICAL DISTANCE 3965.5 48.3 3117.0 146.5 -847.6 4577.7 269.6 6319.4 365.0 1742.6 ~.~.I-'Y 22 710 . 8 0 . 0 710 · 0 29-2 ! ) 2 !0 O NI-Q15 500 . 9 0 . 0 500 . 0 SUMMARY The well which comes closest to the proposed well is: A029-2190500 MI-T22 Closest approach distance = KICK OFF for this run = 14.4 feet 3500.0 feet 15.6 1.3 14.4 201.5 .3T-. - ~SKII .fi- ~4. ooo o,~.. . I I I D9 '-o ; .9 FL/IA/ Vl£ N - 1. E yE L ~ ~ ~l.J _L II _ I IJ._lJ _ l .... IL ..... ~ _ltl I II ~--... ~-- IF IN DOUBT - . -ASK~I Il I ~ II II II . _ I IJ J- I~ .... I_ __]2] £ ~ ]..; :- ~ -. 2~ '_0° I/7 DOYON DRILLING, INC. RI G NO. 15 MUD AND SOLIDS CONTROL EQUIPMENT Equ i pmen t Shaker Desander Mudcleaners Centri fuge Manufacturer Brandt Demco Tri Flow Model Dual Double 2-12" cones Nominal Capacity Double 8 each - 4" cones 1000 9pm 700 9pm (each) 400 9Pm (each) Pioneer Mark II, 150 9pm Decanting Degasser Drilco Agitators Brandt Vacuum 1000 9pm 8 each - 25 h.p. Hoppers Geosource Dual Sidewinders lO00 gpm The trip tank and mud tank sections have one vertical pit level float indicator which are connected to the drilling recorder system that contains visual and audio warning devices located in the driller's console. Interval ENDICOTT MUD PROGRAM MAIN PRODUCTION ISLAND WELL 1-67/T-20 Mud Weight Viscosity (ppg) (sec/qt) Fluid Loss (ml/30min) _I2H_ 0-2500 8.8-9.8 100-200 20-15 9.0-9.5 2,500- 10,908 10,908- 12,113 Set 13-3/8" casing 9.2-10.2 40-45 Mud Type/ Components Set 9-5/8" casing 9.6-10.2 40-45 Generic Mud #5 Hang 7" Liner Seawater Fresh water Gel Soda Ash 15-16 9.0-10.5 Generic Mud #7 6-8 9.0-11.0 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 t. j 13-~/g" API-SO00~ 13-5/8" AP1-3000~ CONTROL LINE-- WELLHEAD ASSEMBLY,ENDICOTT 5KSI 13-3/8"x 9-5/8"× 4-1/2" SOHIO ALASKA PETROLEUM COMPANY F ICURE I (3) 13-3/8" CONTROL LINE 4-1/2:' (6t) · ]qnop uI Jl matt] ~aq~ $XenIV · ~nld asa] 'd'O'fl att] ~uIIIn(t ao ~u[uuna aaqaIa aitttn peat! atl~ jo oaoq atI] o~u! ~u~pna~o~d sna~s~oI -~nld -]at;tie 006 st~°aos~tv°I -(doas aa~ol t,o puuI Illt~ 2t) puoq o2u! ~nld '9118Cc~ 'oN .~-~:,1 'l tuo21 solaosso:~vV ' L~nld a s;~:~ ',! 'O'll tlSn l:I I vuao2uI 7,/l-t/ x ..[ I dn o-)lr, m 'puotlpi)ads :ii[ds o:1 tin poldd.tu oat.' s,'d'O'it aa:lJV 'I ~gVZS ',t'0'~ 9NI£S2£ I'[ .LN:4N,IlflbL4 (IV'Ail'lq2/'1 (INV 9NISV9 ..8'/(~-6 'i2 '11 ~,. SPL I T SPEEDHEAD mH TEST PLUG 13-3/B" O.D. CASING (30) /~-~ IF FE~LE THO ACCESSORIES ITEM 6 II Il II 2~ 0 BOP TEST PLL~3 FOR UPPlER BOWL 1538117l ~2.98 DIA /~-~/2 Ir rE~ALE THO · ACCESSORIES ITEM 7 210 i ·,-= '" .... ~ '~: ~' PL .,'5 .~Or, LOWER BOWL ,c (19) II. 4. 4-1/2 TUBING AND I4ELLItEAD EQUIPMENT 4.1 TESTING B.O.P.'s 1. After 9-5/8" bas been set and tested, run in B.O.P. test plu?~, Accessory Item 6, Part Number 538117, which lands in upper bowl of the split speedhead. Run in 4 lockscrews l£~;ht ly, 90° apart to keel) plug from mov fkn~ · 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 ,sed for the long protector. 4. After bowl protector is tn place, run In 4 lockscrews lightly 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 PORT --LOCKSCREW CASING HANGER SPLIT SPEEDHEAD 13-3/8 --9-5/8 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 24, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn' Mr. C. V. Chatterton 1-67/T-20 MPI (Endicott) Enclosed, in triplicate, is form 10-401, our Application for Permit to Drill the above-named well. Also included are the attachments listed on the application form, and a check in the amount of $100 to cover the permit filing fee. Yours very truly, M. E. Miller Endicott Lead Engineer MEM/KTH CC Richard Loveland ~._ Well File RECEIVED OCT 2 5 1989 Alask~ 0J~ & Gas Cons. CommJsslor~ Anchorage Picks for Nell I - E 7/'T- 2' 0 A F' I ~ 5 0 0 ;2'La 2 i ? 8 5 0 0 Mea'su?ed · 10646.00 i0942~ qO P'la~" k er C Ap p Qu al P i cF'.. Co;=-. u~ Code Co:de Date T L! F F 0 i' 0 ?, - J A N - S~- 0 PT HZ ._.n I ,_,n S! -JAN - :.=..~ F~ PE:HZ Cf i O 9-,]'AN- S~ () TPTR 0 I N0 0 L C: U 0 t 0 S: - J AN- ? 0 TL°B 8 i NO F~_. ,. :- ._, . ...... ':~. -- 'i' '~ hq -- c~ Q TF.'.EK n i r, ,-- '." ...... q L: ;; -- ,J i~ I'q '-' ? K :3 C 0 ! 0 9-JAN - 9 0 ]" S C U 0 ); 0 ':'-)- JAN..,~ 3, 0 S._ ':: c..~, ;. ~ O ~ r,.., ~ ......... -, f P~. i'q - S'-' r , S Si C: 4 0 I 0 S - JAN- 9 R '-' .a J. C: r'~p 1:h i"¢ 9210 ~ 65 946:3, ,--"' 9 'S:~802,68 9 5_ 0 2.68 ~..,' ]. a t e d t ) f t 2 5 2' 7 -,? i 2.4 C! 5'.? 7"&:: i": :.--.-: 4 7' ''~ 2 ,':'i. i'-! = q 7 ;z; Fi :? ,-:I ,J., 7-": 1 '2' L] 6 Cf]a?' Pio. d~: Rep. i ace F'ase '~ CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) L o c ,~Pc'. /~, (j thru 8) (8) · (9 -thru ' 10. ~. ~, ~z, /o-~-~ ~. (10 and 13) 12. 13. (14 thru 22) (5) BOPE ~.~/~., ,&.m,~-~ (23 thru 28) Company Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. .~-/ 3. Is we~] located proper distance from property line .................. / 4. Is w~,~ilocated proper distance from other wells ................ .... ~ 5. Is su.zfiCient 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 ...................... / Lease&WellYES NO No. ,, 14. 15. 16. 17. 18. 19. 20. 21 22. 23. 24 25 26 27. 28. 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 ....................... ,. k/' Is conductor string provided '.'..~?k..., ............................... Will surface casing protect all:zones reasonably expected to serve as an underground sourca.:~:i"arinking water ..................... Is enough cement used to ~:ircu't:~i:~on conductor and surface . ~,. '~ .... . eeeeeeee Will cement tie in surfac~'an~':~'..rmediate or production strings ... Will cement cover all known p~da~'ive horizons ..................... Will all casing give adequate ~~ in collapse, tension and burst.. IsiS oldthiSwellboreWell to ~a~kr~e~n~f[r~{~ i~i~ ~11~3 ........... · · Is adequate wellbore separation~:p~:~osed ............................ Is a diverter system required ,'~.,~a~ ................................. Is the driiling fluid program s~~'tic and list of equipment adequate~ A~ n~essa~ diagrams and :d~sc~:ons o~ ~~ ~OP~ atta~d.~ ~o~ ~oP~ ~aw su~Sici~=t pr~ss~'~ting - T~t to a~~o P~ig .. Does the choke manifold comply w~I~-53 (May 84) .... ~ ............. Is the presence of H2S gas prob~Z~:~:~ ................................ ,v , (6) OTHER ~.?~ '(29 thru 31) (6) Add: Geology: Engineering: DWJ_~'-~ S B EW 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 ............................................. /~fz . W 2f~', L~2~I/ tMl-r ~,' ~_ Additional Remarks: ~v ~_~ ~ ;^/ /z/z 022 Y-z,~ ~ 7.&~. ~-~_v ~ '~. - / - " - INITi'AL GEO. UNIT ! ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1-67 / T-20 ENDICOTT RECEIVED NOV 2. 2 1994 oil & Gas ¢o.~. Run 1' 27 - October - 1994 PDK-100/GR Borax Log 11280 MICROFILMED WESTERN ~__ , ,,/olo,//oo .... , ATLAS.. Atlas Wireline Services, Tape Subfile 2 is type: LIS TAPE HEADER ENDICOTT 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 1-67 / T-20 500292198500 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 15-NOV-94 5709.04 K. BRUNNER J. POWERS 36 12N 16E 2230 2224 55.10 55.10 14.50 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH 11287.0 11287.5 11328.5 11329.0 11329.5 11329.5 11330.5 11330.5 11331.0 11331.5 11331.5 11332.0 11332.5 11332.5 11333.5 11333.5 11334.0 11334.5 11350.5 11351.0 11351.0 11352.0 11351.5 11352.5 11352.0 11353.5 UNKNOWN PBU TOOL CODE: DIL PBU CURVE CODE: GR RUN NUMBER: 2 PASS NUMBER: 1 DATE LOGGED: LOGGING COMPANY: OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 9.625 10962.0 47.00 3RD STRING 7.000 12142.0 29.00 PRODUCTION STRING 4.500 10748.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS 11354.0 ~ 11955.0 11358.0 11359.0 11430.5 11431.0 11439.0 11462.0 11464.0 11464.5 11465.5 11466.5 11474.5 11483.0 11483.5 11484.0 11484.5 11485.5 11497.5 11498.0 11498.5 11499.5 11505.5 11514.5 11516.5 11531.5 11532.5 11533.0 $ REMARKS: 11355.5 11356.0 11359.0 11359.5 11431.0 11432.0 11440.0 11460.5 11462.5 11465.0 11466.0 11467.5 11475.5 11483.0 11483.5 11484.5 11485.0 11485.5 11497.5 11498.5 11499.0 11499.5 11505.5 11512.5 11514.5 11531.0 11532.0 11532.5 PDK-100/GR Borax Log. LOG TIED INTO CBT RUN 10-DEC-89. LOGGING PROGRAM ORGANIZATION: 1. PUMPED HOLE VOLUME + 60 BBLS SEAWATER 2. LOGGED BASE SEAWATER PASS WHILE INJECTING 1/4 BPM. 3. LOGGED BORAX PASS 1:20 BBLS BORAX AWAY. 4. LOGGED BORAX PASS 2:50 BBLS BORAX AWAY. 5. LOGGED BORAX PASS 3:80 BBLS BORAX AWAY. 6. PUMPED 20 BBLS SEAWATER FLUSH. 7. LOGGED FLUSH SEAWATER PASS. A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR THE BASE SEAWATER PASS. THE CURVE IS NAMED SGNT AND WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8" CASING SIZE = 7" SALINITY = 25,000 PPM A PDK POROSITY CURVE (PHI) WAS ALSO CREATED FOR THE BASE SEAWATER PASS. SHIFT PROCEDURE AS FOLLOWS: 1. FIRST PASS GAMMA RAY DEPTH MATCHED TO PREVIOUS 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. / ? ?MATCH1A . OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 1 DEPTH INCREMENT: .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 11283.0 11295.0 STOP DEPTH 11530.0 11542.0 (MEASURED DEPTH) BASELINE DEPTH SGMA 11311.0 11312.0 11314.5 11315.5 11324.0 11324.0 11324.5 11324.5 11325.5 11325.0 11326.0 11325.5 11326.5 11326.5 11328.0 11328.0 11328.5 11329.0 11349.5 11350.0 11350.0 11351.0 11351.0 11352.0 11351.5 11353.0 11354.0 11355.5 11356.5 11357.0 11357.0 11358.0 11364.0 11365.0 11364.5 11366.0 11365.0 11366.5 11404.5 11408.0 11408.0 11411.5 11428.0 11429.0 11430.0 11431.0 11440.5 11441.0 11444.5 11445.0 11445.5 11445.5 11453.0 11453.0 11468.0 11470.5 11468.5 11471.0 11469.0 11472.0 11469.5 11472.5 11470.5 11473.0 11471.5 11473.5 11472.5 11474.5 11473.5 11475.0 11478.0 11479.5 11479.0 11480.0 11481.0 11482.0 11482.5 11483.0 in separate files. EQUIVALENT UNSHIFTED DEPTH 11489.0 · 11490.0 11491.5 11495.5 11498.0 11499.0 11500.5 11502.0 11510.5 11512.0 11512.5 11518.0 11518.5 11520.0 11520.5 11521.5 11526.0 11526.5 $ REMARKS: 11489.5 11490.0 11491.5 11494.0 11496.5 11498.0 11499.5 11502.5 11511.0 11512.0 11512.5 11518.5 11519.0 11521.0 11521.5 11522.0 11526.5 11527.0 BASE SEAWATER PASS. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. /? ?MATCH1B. OUT $ CN : BP EXPLORATION WN : 1-67 / T-20 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 PDK 68 1 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 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 15 SGNT PDK 68 1 CU 16 PHI PDK 68 1 PU-S * DATA RECORD (TYPE# 0) Total Data Records: 39 958 BYTES * 64 4 00 201 24 4 00 201 24 Tape File Start Depth = 11545.000000 Tape File End Depth = 11275.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9198 datums Tape Subfile: 2 258 records... Minimum record length: Maximum record length: 62 bytes 958 bytes T~pe Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 11382.0 11383.5 11384.0 11384.5 11385.5 11388.5 11389.0 11392.5 11400.5 11412.5 11416.0 11416.5 11417.5 11421.5 11422.5 11424.5 11425.5 11430.0 11431.0 11431.0 11433.0 11434.5 11434.0 11435.5 11443.0 11444.0 11444.5 11445.0 11445.0 11445.5 11446.0 11446.0 11450.5 11451.0 11451.5 11451.5 11454.0 11453.5 11455.0 11454.5 11456.0 11458.5 11457.5 11465.0 11464.0 11466.5 11469.0 11470.0 11470.0 11471.5 START DEPTH 11368.0 11380.0 STOP DEPTH 11530.0 11542.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 11384.5 11386.0 11387.0 11387.5 11388.0 11391.0 11392.0 11395.5 11404.0 11416.0 11418.5 11419.0 11419.5 11423.5 11424.0 11431.5 11432.0 11444.0 11444.5 11451.0 11452.0 11457.0 11469.5 11472.0 11472.5 11474.0 11472 11477 11479 11480 11483 11485 11488 11489 11491 11493 11494 11496 11500 11502 11503 11504 11506 11510 11524 11525 11525 11535 11535 $ REMARKS: .5 11473.5 11474.5 .0 11479.0 .0 11480.5 .5 11482.0 .0 11484.0 .0 11485.5 .5 11489.5 .5 11490.0 .0 11491.5 .5 11494.0 .5 11494.0 .0 11497.0 .5 11500.0 .5 11503.5 .5 11504.0 .0 11504.5 .0 11506.0 .5 11509.5 11511.5 .5 11523.5 11525.5 .0 11526.0 .5 11525.0 .0 11534.5 .5 11536.0 BORAX PASS 1:20 BBLS AWAY. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH2A. OUT /??MATCH2B.OUT $ CN : BP EXPLORATION WN : 1-67 / T-20 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units GRCH PDK 68 1 GAPI BIF PDK 68 1 BKL PDK 68 1 CPS BKS PDK 68 1 CPS CSLS PDK 68 1 CU LS PDK 68 1 CPS MSD PDK 68 1 CU RATO PDK 68 1 RBOR PDK 68 1 Size API API API API Log Crv Crv Length Typ Typ Cls Mod 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 O0 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 10 RICS PDK 68 1 11' RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS * DATA RECORD (TYPE# 0) Total Data Records: 34 966 BYTES * 56 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 Tape File Start Depth = 11545.000000 Tape File End Depth = 11275.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8116 datums Tape Subfile: 3 128 records... Minimum record length: 62 bytes Maximum record length: 966 bytes T~pe Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 11286.0 11298.0 BASELINE DEPTH 11299.0 11303.5 11312.5 11313.5 11318.0 11320.5 11321.5 11324.5 11325.5 11327.0 11328.0 11328.5 11330.5 11331.0 11332.0 11332.5 11350.5 11353.0 11353.5 11355.5 11356.5 11365.5 11367.0 11367.5 11369.0 11374.0 11374.5 11381.5 11382.0 11389.0 11390.5 11401.0 11403.0 11412.0 11413.0 11413.5 11416.5 GRCH 11318.5 11327.5 11328.0 11332.0 11333.0 11351.0 11354.0 11356.5 11357.0 11367.5 11368.5 STOP DEPTH 11530.0 11542.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 11299.0 11304.5 11313.5 11314.0 11321.0 11321.5 11324.5 11325.0 11327.5 11328.5 11330.5 11331.5 11351.0 11354.5 11366.5 11370.5 11375.5 11376.5 11383.5 11384.5 11391.5 11393.5 11404.0 11406.5 11415.5 11416.0 11416.5 11419.0 11417.5 1149~ 1.0 11422.0 11425.0 11425.5 11426.0 11429.5 11433.5 11434.5 11435.5 11447.5 11448.5 11450.0 11450.5 11451.5 11454.5 11456.0 11463.5 11464.5 11465.0 11466.5 11469.5 11470.5 11473.5 11474.5 11477.0 11479.5 11484.5 11485.5 11491.0 11493.5 11496.0 11501.0 11504.0 11505.0 11506.5 11511.0 11521.5 11522.0 11522.5 11523.0 11523.5 11524.5 11525.5 11534.5 11535.0 $ REMARKS: 11426.0 11426.5 11436.0 11449.5 11451.0 11453.5 11462.5 11463.0 11463.5 11486.0 11494.0 11496.0 11504.0 11504.5 11506.0 11509.5 11521.0 11522.0 11523.5 11525.0 11534.0 11534.5 11419.5 11423.0 11423.5 11427.0 11430.5 11434.5 11435.0 11448.0 11448.5 11450.0 11451.0 11456.5 11469.0 11472.0 11472.5 11475.5 11476.0 11478.5 11480.5 11485.5 11486.0 11491.5 11495.0 11500.0 11511.5 11522.0 11523.0 11524.5 11525.0 BORAX PASS 2:50 BBLS AWAY. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN / ??MATCH3A. OUT / ? ?MATCH3 B. OUT $ : BP EXPLORATION : 1-67 / T-20 : ENDICOTT : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 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 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 MSD PDK 68 1 CU 4 8 RATO PDK 68 1 4 9 RBOR PDK 68 1 4 10 RICS PDK 68 1 4 11 RIN PDK 68 1 4 12 SGMA PDK 68 1 CU 4 13 SGMB PDK 68 1 CU 4 14 SS PDK 68 1 CPS 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 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 34 Tape File Start Depth = 11545.000000 Tape File End Depth = 11275.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17314 datums Tape Subfile: 4 151 records... Minimum record length: 62 bytes Maximum record length: 966 bytes T~pe S~bfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 11364.0 PDK 11376.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 for each pass in separate files. STOP DEPTH 11530.0 11542.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 11380.5 11385.5 11385.5 11388.5 11390.5 11389.0 11391.5 11392.5 11395.0 11403.0 11406.0 11412.5 11415.5 11416.0 11418.0 11417.0 11419.0 11418.0 11419.5 11422.5 11424.0 11423.5 11424.5 11424.0 11425.0 11424.5 11425.0 11425.0 11425.5 11426.0 11426.0 11429.5 11430.0 11431.0 11431.0 11432.5 11433.0 11433.0 11433.5 11433.5 11434.0 11434.5 11436.5 11437.0 11442.0 11442.5 11443.0 11443.0 11444.5 11444.0 11451.5 11451.0 11452.5 11452.5 11453.0 11453.5 11454.0 11453.0 11455.5 11456.0 11459.0 11457.5 11464.0 11462.5 11465.0 11463.0 11465.5 11463.5 11466.0 11468.0 11468.5 11469.0 11470.0 11472.0 EQUIVALENT UNSHIFTED DEPTH SGMA 11382.5 11471.0 11474.0 11477.0 11483.5 11487.5 11488.5 11491.0 11495.0 11499.0 11501.0 11504.5 11505.5 11507.0 11511.0 11517.5 11519.0 11519.5 11524.0 11524.5 11525.5 11534.5 11535.0 $ REMARKS: 11472.5 11474.5 11478.5 11484.0 11488.0 11488.5 11491.0 11493.5 11498.5 11499.5 11504.0 11504.5 11506.0 11509.0 11511.0 11515.5 11519.0 11518.0 11520.0 11524.5 11523.0 11525.0 11525.0 11534.0 11534.5 BORAX PASS 3:80 BBLS AWAY. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH4A. OUT / ? ?MATCH4B. OUT $ CN : BP EXPLORATION WN : 1-67 / T-20 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code 1 GRCH PDK 68 2 BIF PDK 68 3 BKL PDK 68 4 BKS PDK 68 5 CSLS PDK 68 6 LS PDK 68 7 MSD PDK 68 8 RATO PDK 68 9 RBOR PDK 68 10 RICS PDK 68 Samples Units 1 GAPI 1 1 CPS 1 CPS 1 CU 1 CPS 1 CU 1 1 1 Size API API API API Log Crv Crv Length Typ Typ Cls Mod 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 11 RIN PDK 68 1 12' SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS * DATA RECORD (TYPE# 0) Total Data Records: 34 4 4 00 201 24 4 4 00 201 24 4 4 00 201 24 4 4 00 201 24 56 966 BYTES * Tape File Start Depth = 11545.000000 Tape File End Depth = 11275.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16232 datums Tape Subfile: 5 127 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape S~bfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 5 DEPTH INCREMENT: .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 11280.0 11292.0 STOP DEPTH 11530.0 11542.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 11275.0 11275.0 11287.5 11287.5 11304.5 11305.0 11317.0 11317.5 11320.5 11320.5 11323.5 11323.5 11323.5 11324.5 11324.0 11328.0 11327.5 11328.5 11328.5 11330.0 11330.0 11330.5 11331.0 11339.0 11339.0 11341.5 11341.5 11345.5 11346.0 11352.5 11353.0 11353.0 11354.0 11360.5 11361.0 11363.0 11363.0 11366.0 11367.0 11368.5 11370.0 11372.0 11373.5 11372.5 11374.5 11379.0 11381.0 11380.0 11382.5 11383.5 11383.5 11386.5 11386.5 11389.0 11389.5 11389.5 11392.0 11391.0 11394.0 11393.0 11396.0 11396.0 11399.5 11404.0 11405.0 11405.5 11406.5 11409.0 11406.5 11407.0 11409.5 11407.0 11407.5 11407.5 11408.5 11413.5 11416.5 in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 11275.0 11415.5 11416.5 11418.5 11419.5 11426.5 11427.5 11434.0 11435.0 11439.0 11442.0 11443.0 11445.0 11446.0 11452.0 11453.5 11454.0 11455.0 11456.0 11462.0 11464.0 11464.5 11465.0 11469.5 11470.5 11476.0 11476.5 11477.0 11477.5 11479.5 11480.5 11486.0 11487.0 11490.0 11491.5 11494.5 11500.5 11501.0 11501.5 11502.5 11503.5 11504.5 11505.0 11506.0 11507.5 11508.5 11514.0 11515.0 11518.5 11519.0 11524.5 11525.0 11529.0 11535.0 11535.5 11545.0 $ REMARKS: 11427.5 11435.0 11435.5 11439.5 11445.5 11446.0 11452.0 11453.0 11454.5 11455.0 11463.5 11466.5 11471.0 11471.5 11477.0 11477.5 11490.5 11504.0 11504.5 11505.0 11505.5 11507.0 11507.5 11523.5 11524.5 11529.0 11418.0 11418.5 11420.5 11421.0 11428.0 11428.5 11443.0 11443.5 11454.0 11455.0 11457.0 11464.0 11466.0 11467.0 11472.0 11472.5 11478.5 11479.0 11481.0 11481.5 11487.0 11487.5 11492.0 11494.0 11500.0 11500.5 11501.5 11502.5 11506.0 11515.0 11515.5 11519.0 11520.0 11536.0 11536.5 11545.0 FLUSH SEAWATER PASS: 20 BBLS SEAWATER AWAY. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ??MATCH5A . OUT /??MATCH5B.OUT $ CN : BP EXPLORATION WN : 1-67 / T-20 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS 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 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 56 * DATA RECORD (TYPE# 0) Total Data Records: 34 966 BYTES * Tape File Start Depth = 11545.000000 Tape File End Depth = 11275.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 25430 datums Tape Subfile: 6 160 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape S~bfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11282.0 PDK 11294.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11541.0 11553.0 27-OCT-94 FSYS REV. J001 VER. 1.1 1022 27-OCT-94 11555.0 11554.0 11280.0 11544.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC TEMP TEMPERATURE $ TOOL NUMBER 2725XA 2324XA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 12142.0 0.0 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): SEA H20/BORAX 0.00 0.0 190.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 900 FAR COUNT RATE HIGH SCALE (CPS): 3400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: BASE SEAWATER PASS. $ CN : BP EXPLORATION WN : 1-67 / T-20 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 ,Curves: Name Tool Code Samples Units 1 GR PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CCL PDK 68 1 6 CSLS PDK 68 1 CU 7 CSS PDK 68 1 CPS 8 ISS PDK 68 1 CPS 9 LS PDK 68 1 CPS 10 MON PDK 68 1 CPS 11 MSD PDK 68 1 CU 12 RATO PDK 68 1 13 RBOR PDK 68 1 14 RICS PDK 68 1 15 RIN PDK 68 1 16 SGMA PDK 68 1 CU 17 SGMB PDK 68 1 CU 18 SPD PDK 68 1 F/MN 19 SS PDK 68 1 CPS 20 TEN PDK 68 1 LB 21 SGNT PDK 68 1 CU 22 PHI PDK 68 1 PU-S API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 06 511 09 0 4 4 00 201 24 1 4 4 39 705 61 6 4 4 74 169 61 6 4 4 92 630 79 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 71 162 89 6 4 4 71 162 89 6 4 4 32 125 68 0 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 52 386 28 5 4 4 05 626 89 6 4 4 17 922 28 5 4 4 00 201 24 1 4 4 00 201 24 1 88 * DATA RECORD (TYPE# 0) Total Data Records: 99 1018 BYTES * Tape File Start Depth = 11553.000000 Tape File End Depth = 11282.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 41188 datums Tape Subfile: 7 175 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE S~RY VENDOR TOOL CODE START DEPTH GR 11367.0 PDK 11379.0 $ LOG HEADER DATA STOP DEPTH 11542.0 11554.0 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 SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC TEMP TEMPERATURE $ 27-OCT-94 FSYS REV. J001 VER. 1.1 1153 27-OCT-94 11555.0 11554.0 11280.0 11544.0 900.0 YES TOOL NUMBER 2725XA 2324XA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 12142.0 0.0 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): SEA H20/BORAX 0.00 0.0 190.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 900 FAR COUNT RATE HIGH SCALE (CPS) : 3400 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): 0.0 REMARKS: BORAX PASS 1:20 BBLS AWAY. $ CN : BP EXPLORATION WN : 1-67 / T-20 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 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 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 ISS PDK 68 1 CPS 4 9 LS PDK 68 1 CPS 4 10 MON PDK 68 1 CPS 4 11 MSD PDK 68 1 CU 4 12 RATO PDK 68 1 4 13 RBOR PDK 68 1 4 14 RICS PDK 68 1 4 15 RIN PDK 68 1 4 16 SGMA PDK 68 1 CU 4 17 SGMB PDK 68 1 CU 4 18 SPD PDK 68 1 F/MN 4 19 SS PDK 68 1 CPS 4 20 TEN PDK 68 1 LB 4 4 06 511 09 4 00 201 24 4 39 705 61 4 74 169 61 4 92 630 79 4 00 201 24 4 00 201 24 4 71 162 89 4 71 162 89 4 32 125 68 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 52 386 28 4 05 626 89 4 17 922 28 ~mm--mmm 80 0 1 6 6 6 1 1 6 6 0 1 0 0 0 0 6 1 5 6 5 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 63 T~pe File Start Depth = 11554.000000 Tape File End Depth = 11367.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 41160 datums Tape Subfile: 8 139 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Ta~e S~bfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11284.0 PDK 11296.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11542.0 11554.0 27-OCT-94 FSYS REV. J001 VER. 1.1 1220 27-OCT-94 11555.0 11554.0 11280.0 11544.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC TEMP TEMPERATURE $ TOOL NUMBER 2725XA 2324XA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 12142.0 0.0 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): SEA H20/BORAX 0.00 0.0 190.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 900 FAR COUNT RATE HIGH SCALE (CPS): 3400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS. · BORAX PASS 2:50 BBLS AWAY. $ CN : BP EXPLORATION WN : 1-67 / T-20 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA '* FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 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 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 ISS PDK 68 1 CPS 4 9 LS PDK 68 1 CPS 4 10 MON PDK 68 1 CPS 4 11 MSD PDK 68 1 CU 4 12 RATO PDK 68 1 4 13 RBOR PDK 68 1 4 14 RICS PDK 68 1 4 15 RIN PDK 68 1 4 16 SGMA PDK 68 1 CU 4 17 SGMB PDK 68 1 CU 4 18 SPD PDK 68 1 F/MN 4 19 SS PDK 68 1 CPS 4 20 TEN PDK 68 1 LB 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 71 162 89 6 4 71 162 89 6 4 32 125 68 0 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 52 386 28 5 4 05 626 89 6 4 17 922 28 5 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 91 Tape File Start Depth = 11554.000000 T~pe File End Depth = 11284.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 63890 datums Tape Subfile: 9 167 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape S~bfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11363.5 PDK 11375.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11541.0 11553.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC TEMP TEMPERATURE $ 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): 27-OCT-94 FSYS REV. J001 VER. 1.1 1253 27-OCT-94 11555.0 11554.0 11280.0 11544.0 900.0 YES TOOL NUMBER 2725XA 2324XA 2120XA 0.000 12142.0 0.0 SEA H20/BORAX 0.00 0.0 190.0 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): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 900 FAR COUNT RATE HIGH SCALE (CPS): 3400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: BORAX PASS 3:80 BBLS AWAY. $ CN : BP EXPLORATION WN : 1-67 / T-20 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 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 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 ISS PDK 68 1 CPS 4 9 LS PDK 68 1 CPS 4 10 MON PDK 68 1 CPS 4 11 MSD PDK 68 1 CU 4 12 RATO PDK 68 1 4 13 RBOR PDK 68 1 4 14 RICS PDK 68 1 4 15 RIN PDK 68 1 4 16 SGMA PDK 68 1 CU 4 17 SGMB PDK 68 1 CU 4 18 SPD PDK 68 1 F/MN 4 19 SS PDK 68 1 CPS 4 20 TEN PDK 68 1 LB 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 71 162 89 6 4 71 162 89 6 4 32 125 68 0 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 52 386 28 5 4 05 626 89 6 4 17 922 28 5 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 64 Tape File Start Depth = 11553.000000 T~pe File End Depth = 11363.500000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 57100 datums Tape Subfile: 10 140 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Ta~e S6bfile 11 is type: LIS FILE HEADER FILE NUMBER: 10 RAW CURVES Curves and log header data for each run in separate files; raw background p_~=~ J n la~. f~l~, PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11279.5 PDK 11291.5 $ LOG HEADER DATA STOP DEPTH 11542.0 11554.0 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 SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC TEMP TEMPERATURE $ 27-OCT-94 FSYS REV. J001 VER. 1.1 1322 27-OCT-94 11555.0 11554.0 11280.0 11544.0 900.0 YES TOOL NUMBER 2725XA 2324XA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 12142.0 0.0 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): SEA H20/BORAX 0.00 0.0 190.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 900 FAR COUNT RATE HIGH SCALE (CPS) : 3400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): 0.0 REMARKS: FLUSH SEAWATER PASS: 20 BBLS SEAWATER AWAY. $ CN : BP EXPLORATION WN : 1-67 / T-20 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 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 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 ISS PDK 68 1 CPS 4 9 LS PDK 68 1 CPS 4 10 MON PDK 68 1 CPS 4 11 MSD PDK 68 1 CU 4 12 RATO PDK 68 1 4 13 RBOR PDK 68 1 4 14 RICS PDK 68 1 4 15 RIN PDK 68 1 4 16 SGMA PDK 68 1 CU 4 17 SGMB PDK 68 1 CU 4 18 SPD PDK 68 1 F/MN 4 19 SS PDK 68 1 CPS 4 20 TEN PDK 68 1 LB 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 71 162 89 6 4 71 162 89 6 4 32 125 68 0 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 52 386 28 5 4 05 626 89 6 4 17 922 28 5 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 88 ~ Tape File Start Depth = 11554.000000 ~ape File End Depth = 11291.500000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 85962 datums Tape Subfile: 11 164 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes TaPe S6bfile 12 is type: LIS 94/11/15 01 **** REEL TRAILER **** 94/11/15 01 Tape Subfile: 12 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 15 NOV 94 2:13p Elapsed execution time = 8.51 seconds. SYSTEM RETURN CODE = 0
