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Home My WebLink About196-132Originated:Delivered to:16-Oct-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-13 50-029-21286-00 906617822 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 2 3H-20 50-103-20093-00 906518944 Kuparuk River Leak Detect Log Field- Final 2-Jul-20 0 1 3 3N-07 50-029-21539-01 906614634 Kuparuk River Plug Setting Record Field- Final 23-Jul-20 4 3N-07 50-029-21539-01 906604302 Kuparuk River String Shot Record Field- Final 16-Jul-20 5 3N-07 50-029-21539-01 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 6 2K-04 50-103-20099-00 906595531 Kuparuk River Multi Finger Caliper Field& Processed 9-Jul-20 7 2K-04 50-103-20099-00 906595531 Kuparuk River Plug Setting Record Field- Final 8-Jul-20 8 3A-17 50-029-22691-01 906634080 Kuparuk River Plug Setting Record Field- Final 2-Aug-20 0 1 9 3K-23 50-029-22771-00 906648363 Kuparuk River Tubing Punch Record Field- Final 10-Aug-20 0 1 10 3N-19 50-029-23056-00 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 Received by the AOGCC 10/16/2020 10/20/2020 Abby Bell PTD: 1961320 E-Set: 34121 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 30, 2010 ~, . `; if,?, RE: Plug Setting Record: 3A-17 Run Date: 8/27/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A-17 Digital Data in LAS format, Digital Log Image file 50-029-22691-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 9 - - 53.5 klinto " ~~ 1- ~-'' ~~~ `° '' ~ ' I f %,~ _ . Date: aa`` T`~C~~c3a ~BC~~Y Signed: ~ PltoAcTive Dinynas~ic Sl=evicg, Inic. • • U~f~LL. ~QG 1"R.4~11~1t~/T7~4~ - To: AOGCC Christine Mahnken 3S3 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C -, 'i' . .. °~~r~ ... C~ Anchorage, AK 99518 Fax: (907j 245-6952 1) Caliper Report 2) 19 Aug-10 ~q~_`3~ 3A-17 1 Report / EOE 50-029-22691-00 ;, ~~ j Signed Print Name: t-, fi3 '7 i ' ` i 1 ,~ ~J ty; ~ :~ ~ r ;~ j U Date .:~;~ .. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907j245-8961 FAX: (907)245-88952 E-MAIL : ta~sanc~oraa~t~e?~~s~sor~~ WEBSITE : =rv~~r~.s~er~ot~d~log.~os~ c:~Doaunentis sna semn~s~iane w~n~rop~7Y~,smit_c~o.ao~ • Memory Multi-Finger Caliper Log Results. Summary Company: ConocoPhillips Alaska, Inc. Well: 3A-17 Log Date: August 19, 2010 Field: Kuparuk Log No.: 7437 State: Alaska Run No.: 2 API No.: 50-029-22691-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD MOD Top Log Intvl1.: 6,814 Ft. (MD) Pipet Use: Tubing and Liner Bot. Log Intvl1.: 7,459 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage COMMENTS This caliper data is tied into the Camco D-Nipple @ 7,251' (Driller's Depth). This log was run to assess the condition of the tubing and finer with respect to corrosive and mechanical damage prior to CTD sidetrack operations. A 3-D log plot of the caliper recordings across the 3.5" liner logged is included in this report The caliper recordings indicate the 3.5" tubing and liner logged appear to be in good condition, with no significant wall penetrations or areas of cross-sectional wall loss recorded. Deposits are recorded throughout the 3.5" liner logged, restricting the I.D. to 2.67" in joint 222 (7,315'). Although the caliper fingers were restricted to 2.67", a gauge ring with a larger diameter may not be impaired by these deposits because of the difference in force exerted during a drift compared to a caliper arm during normal logging speeds. A graph illustrating minimum recorded diameters on a joint-by joint basis is included in this report. This is the second time a PDS caliper has been run in this well and the first time the 3.5" liner has been logged from 7,298' to 7,459'. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 16°!0} are recorded throughout the tubing and liner logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Minimum I.D. = 2.67" Jt. 222 @ 7,315 Ft. (MD) Deposits Minimum I.D. = 2.72" Jt. 221 @ 7,300 Ft. (MD) No other significant I.D. restrictions are recorded throughout the tubing and liner logged. Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: M. Hazan RruA.Ctl've Diai~naStiC Services, Ii iC. j P.O. BoY. 1369, Stafford, TX 77497 Phone: (281} or (888) 565-9085 Fax: (281) 565-1369 E.-mail: PDS@memoryioq.COm Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~°~~- t3a ava ~~ • PDS Multifinger Caliper 3D Log Plot ~, ~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3A-17 Date : August 19, 2010 Description : Detail of Caliper Recordings Across 3.5" Liner dogged. Comments Depth Max. Pen. (%) Maximum LD. 3-D Log Image Map 1ft:240ft 0 100 2.5 inches 3.5 0° 0° 90° 180° 270° 0° Minimum I.D. 2.5 inches 3.5 Nominal I.D. . 2.5 .............. inches...............3.5, 7160 Joint 279 7170 7180 Pup Jc. 7190 cLM s 7200 7210 Pup Jt. 7220 7230 Joint 220 7240 7250 Camco D-Nipple Pup Jt. 7260 Baker GBH-22 Seal Assemby 7270 3.5" Tubing Tail Pup Jt. 7280 Joint 221 Top of 3.5" Liner 7290 Deposits min. i.D. = 2.72" 7300 ilk -~~+ - - ,~ _ ~,_ ;._ r -~ ; .. ._ • • 7310 7320 Joint 222 Deposits 7330 Min. I.D. = 2.67" 7340 - r 7350 Joint 223 7360 Pertorations 7370 7380 Joint 224 7390 Perforations 7400 7410 Joint 225 7420 Lt. Deposits Min. I.D. = 2.77" 7430 7440 Joint 226 Lt. Deposits 7450 Min. I.D. = 2.76'• Joint 227 ~~= _ ~:, ~~. h ~. r `;,' I k, - ~~_ :. „~, Perforations .; $~,. , Perforations ,. ~.,, gym` ,: ~f: . ~~ =` ~. N ice.. ~:~ m w _ Nominal I.D. :..................................................: 2.5 inches 3.5 Minimum I.D. 2.5 inches 3.5 ~ Comments Depth Max. Pen. (%) Maximum I.D. 3-D Log Image Map ' 0 100 2.5 inches 3.5 0° 0° 90° 180° 270° 0°~ • • ~~ Minimum Diameter Profile Well: 3,A-17 Survey Date: August 19, 2010 Field: Kuparuk Tool: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches Minimum Measured Diameters (In.) 1.69 1.94 2.19 2.44 2.69 2.94 209 210 211 212 273 274 275 216 217 218 279 219 219 ~ 219 Z .. c 'S z2o 220 zzo 220 zzo 221 227 22° 223 224 225 226 227 t ^ ^ t ^ ^ ^ ^ I! ^ • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 3A-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: ,August 19, 2010 Joint No. Jt. Depth (Ft.) I'c~n. t II~~~~) (Ir;..) Pen. Body (Ins.) Pen. °/, Mclal I os "~~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 209 6837 (~ Q02 ~~ ~~ 2.89 Lt De osits. 210 6869 i) 0.03 1 _' _' 2.90 Lt. De osits. 21 1 6900 ~) 0.01 (~ 1 2.91 212 6931 ! ~ 0.03 1~ 2.91 213 6963 i.1 0.02 ~t ( 2.90 Ll. De osi is. 214 6995 U 0 0 1 2.89 Lt. De osits. 215 7026 ~ ~ 0.02 ~) I 2.90 Lt. De osits. 216 7058 ~t 0.02 (~ 1 2.91 217 7090 a 0.03 l :i I 2.88 Shallow ittin Lt. De osits. 218 7121 t) 0.01 2 ! ~ 2.87 Lt. De osi ts. 219 7152 n 0.02 ~) i 2.90 Lt. De osits. 219.1 7184 ~~ 0.01 ~ ii 2.89 PUP Lt. De osit<<. 219.2 7197 ~) 0 i) ~i N A GI_.M 6 Latch C~ 12:30 219.3 7204 (~ 0.04 1(> -a 2.92 PUP Sh Ilow line corrosion. 220 7220 i? 0.04 I S I 2.91 Shallow ~ittin I_t. De osits. 220.1 7251 i) 0 0 t) 2.75 Camco D-Ni le No Go 220.2 7253 U 0.00 1 U 2.85 PUP Lt. De osits. 220.3 7259 U 0 0 U N A Baker GBH-22 Seal Assembl w Locator 220.4 7271 i) 0 0 t) N A 3.5" Tubin Tail 220.5 7273 ~i 0 t) i) 2.80 PUP Lt. De osits. 221 7280 0.03 li) I 2.72 To of 3.5" Liner. De osits. 222 7312 U 0.03 tt) 2.67 De osits. 223 7344 ~' 0.15 59 1 ~t 2.77 Perforations. Lt. De osits. -- 224 7376 G. I U 0.28 1 UO ~l1 2.80 Perforations. 2' S 7408 U 0.01 6 U 2.77 Lt. De osits. 226 7439 0 2.76 LL De osits. 21? 7455 U 1.76 Lt De posits. __ Penetration Body Metal Loss Body Page 1 PDS Report Cross Sections ~ ya. S„ Well: 3A-17 Survey Date: August 19, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 tubing: 3.5 ins_ 9.3 ppf L-80 EUE 8RD MOD Anal st: C. Waldro Cross Section for Joint 222 at depth 7314.54 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 °,/~ Tool deviation = 42 " Finger 23 Projection =-0.248 ins Deposits Minimum I.D. = 2.67 ins HIGH SIDE = UP Cross Sections page 1 • PDS Report Cross Sections ~~. ~ Well: 3A-17 Survey Datc: August 19, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EUE SRD MOD Anal st: C. Waldro Cross Section for Joint 221 at depth 7300.21 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 °.~o Tool deviation = 42 " Finger 14 Projection =-0.247 ins Deposits Minimum I.D. = 2.72 ins HIGH SIDE = UP Cross Sections page 2 ~. /~r~.~ KUP ~ 3A-17 ConocoPhillips At t~ Af1 De e~ AD I / WNlbore PWWI 500292269100 Fleltl Name WeN Stan,s Ind 1°) KUPARUK RIVER UNIT PROD 43.27 Y 5.800.00 tm (ftKB) 7.784.0 - Comment X28 (ppm) Dale SSSV: NIPPLE 220 3/1512009 Amotmon Last WO: lstl Dare KB-Grtl pq 46 50 Rig Releau Dae 9/2/1996 w I o"e -. - A-1 sn 1 0^~ a ^~ ° a c3 Pm cnematic-Actual ~ Amotatlon Last Teg: SLM DepM ) 7.435.0 . tl ale Amotatlon 8/12/2010 Rev Reason: TAG Last Imosbor tl aze 8/15/2010 Casin Strin s - MANGER, 37 ,...,. ~ . "' Casing Descrlpbon CONDUCTOR Casing Desraiptlon SURFACE Slnng 0.. 16 Sung 0... 75/8 . Stnrg ID ... 15.062 Sl ID ... 6.059 Top plKe) 9 40.0 oP (RH 1 39.0 e[ Depth (f... 121.0 t DlpM p... 3,821.3 Set ptlt (TVD) ... 121.0 SM DePtll (TVD) ... 3.305.5 S[Nng Wt... 62.50 Suing ... 29.70 atdng ... H~0 rig ... L-80 St ng Top Thrd WELDED Sr Op BTC-MOD ~ Casing Descrlptlon PRODUCTION 5.5"x3.5" Stdrg 0... 51/2 String ID ... 4.950 Top piXB) S 35.0 et DepSr p'... 7,782.0 Set DepM (TVD) ... 6.333.7 Stdng WL.. 15.50 Strbg ... L-80 Stdng Tap Thrtl LTC-MOD Tubin Strin s coNDUaoR, an v~ drg Descrtptlon Strbg 0... String I ... Top B) et Depth (f... Depm (TVD) ... Siting Wt... S[rtng ... S[drg Top 7Trtl TUBING 3112 2.992 36.9 7,272.1 5,935.8 9.30 L-80 EUE 8RD MOD Com letion Details NIPPLE. 50E Top p1KB) Top Depm (ND) T ~B) op Intl (% tt em DescXptlon Comment NoM... 10 pry ~i 36.9 36.9 -0.45 H ANGER FMC GEN IV HANGER 3.500 507.7 507.7 0.72 N IPPLE CAMCO DS Landing Nipple NO GO 2.812 GAS u~, --'_ 7,251.3 5,919.3 37.63 N IPPLE CAMCO D Nipple NO GO; pulled SDartek gauges antl shut in tool from D nipple 3/20/99. 2.750 7,258.4 5.924.9 37.72 S EAL ASSY BAKER GBH-22 SEAL ASSY w/LOCATOR w/ 10' SEALS w/SPACE OUT 3.000 PUP (~ Perforations & Slots II II I I TaPl~el e~l~l Top (Twl CBI Btm (TVD) IRKe) Zone Date a Dens Ish••• type Comment J E as- 2i ~ 7,347 7.370 5,994.5 6.012.5 C-4, 3A-17 6!4!1999 2.0 APERF Abernate 2 1/8" Power EJ. HMX chgs w12 1/S" BH EJ, RDX chgs, rotate 90 deg/repeat 7,380 7,390 6,020.3 6,028.1 UNIT B, 3A-17 6/4/1999 2.0 APERF Alternate 21/8" Power EJ, HMX chgs w/2 1 /8" BH EJ RDX chgs rotate 90 cns uFT. a :36 , , deg/repeat 7,474 7,504 6,093.8 6,117.1 A-3, 3A-17 10/29/1996 2.0 IPERF 180 deg. phasing; 2 1/2" HC Notes: Gerreral & Saf Entl Daze Annotation 719!2005 NOTE TAGGED OBSTRUCTION @ 5250 GAS uFT, 8/25/2005 NOTE: PHANTOM OBSTRUCTION STILL FLOATING DOWNHOLE s,zsa 6/30/2010 NOTE: View Schematic w/Alaska Schematic9.0 CAS L IFI, 6,i~a C-AS L IFf. 8 ]53 GAS LIFT, 19P NIPPLE ] 251 , . SEPL SSY A , 7 258 APERF, ].347-].370 Mandrel Details APERF ],380.1390 Stri To ftlC op DepN (TVD) D]K~ op Intl (°) Make Nbtlel OD (m) Serv Valve TYPe Latch Type ort Size P^) TRO RUi (psi) Run Dale Cam._ 1 2961- 2,654. 5 39.67 BST ATX 1 GAS LIFT GLV T-1 0.156 1,303.0 11!30/1996 2 4,235.5 3,625. 8 40.48 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 9/1411996 3 5,254.5 4,398. 1 40.37 BST ATX 0 GAS LIFT GLV T-1 0.156 1,335.0 11(30/1996 IPERF. 7A7a-7 so4 4 6,114.3 5,034. 5 40.37 &ST ATX t GAS LIFT DMY T-1 0.000 0.0 9/14!1996 6,752.7 5.52 . 5 37.42 B ST ATX 1 GAS LIFT OV T-1 0.188 0.0 2!6/2007 6 7.197.8 5,877. 2 38.07 B ST ATX 1 GAS LIFT DMY T-1 0.000 0.0 2!4/2007 PRODUCTIGN 5'k3 S" 3S] ]82 ~y TD, ] ]84 ~~'d I~~ 0~ adQ~~Q /a~,..~.~~o~,.~. Jill Long Wells Engineer i ConocoPhillips Alaska, Inc. ,~'~~~~~ AUu ~ ~ 201D ~' P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Poo13:P~-17 Sundry Number: 310-261 Dear Ms. Long: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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. 'ncerely, Daniel T. Seamount, Jr. C ~ Chair DATED this Z6 day of August, 2010. Encl. STATE OF ALASKA ~ } 5~~~-JO ALAS LAND GAS CONSERVATION COMMISS ~'`'~' •O w L.~ APPLICATIOpN-/ FO~SUNDRY APPROVALS ~"~' 9~"1•~20 AAC 25.280 1. Type of Request: Abandon ("` Rug for Redrill Perforate New Pool Repair w ell ~ Change Approved R-ogram ('" Suspend ~"" Rug Perforatir`^c Perforate ~ Pull Tubing ~'"" Time Extension ~""' Operational Shutdow n Re-enter Susp. Well ~"' Stimulate ~ Alter casing ~- Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory 196-132 - 3. Address: Stratgraphic ~ Service ~•- 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-22691-00 _ 7. If pertorating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes ~rl No ~` 3A-17 9. Property Designation: 10. Field/Pool(s): (t C - t 1~ I $lP !7Z ADL 25632 - Kuparuk River Field /Kuparuk River Oil Pool ~3 ~ - 1! >~~ 2 to p7~ 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (n): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7785 6336` 7717 6283' Casing Length Size MD ND Burst Collapse CONDUCTOR g1 16 121' 121' SURFACE 3782 7-5/8" 3821' 3306' PRODUCTION 7747 5.5" x 3.5" 7782' 6334' Pertoration Depth MD (ft): ~ Pertoration Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7347'-7370', 7380'-7390', 7474'-7504' 5995'-6013', 6020'-6028', 6094'-6117' 3.5 L-80 7272' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) no packer NIPPLE - CAMCO DS Landing Nipple NO GO MD= 508 ND= 508 12. Attachments: Description Surrmary of Proposal 13. Well Class after proposed work: Detailed Operations Program j" BOP Sketch ~° Exploratory ~'-"' Development ~- Service 14. Estimated Date for Commencing Operations: ~\' 15. Well Status after proposed work: 8/25/2010 Oil ~ Gas ~"` WDSPL ~ Suspended 16. Verbal Approval: te: WINJ ~''•'` GINJ ~ WAG ~ Abandoned I-" Commission Representative: GSTOR ~~ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263-4093 Printed Name JIIIJiII Long Title: Wells Engineer Signature Phone: 263-4093 Date ~6 C nl Sundry Number: ~v ~ ~(„' ///~~' O~~/ Conditions of approval: Notify Commission so that a representative may witness Test Mechanical IntegrityTe~ ~"` Location Clearance Plug Integrity ~` S ~ ~ ~ ~~~~ j~~ ~~ 1~ D O yes ,~~ psi a~ 3 ~..c_ rr~~ ~ ®® Other: ~ Z S'G ~ p S ~- ~- n .L •,~+~~ % S ~ l-x.t,,,~,~ ®l~cc,er..a,-~- Z° _ 0 ~k orotJ~ ~ IrK ~ z ~ ~~. ?-~~~~1 ~C"Z'~/IZ ~ ~ / ~ r - l T Subsequent Form Required: • ,f ', ,y ~t. ~;9~f111SS ~f APPROVED BY ;y ~ (~/ Approved by: COMMISSIONER THE COMMISSION Date: ~ ~~ O(t ~~t%_ D Form 10-403 Revised 1'1'~'A'~Ur~s A~G 3 ~ ~. ~ ~` _ ~ Q Submit in Duplicate Y`2. ~ r ~~/,o • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 18, 2010 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundries to plug all perforations in wellbore: 3A-17 (PTD# 196-132). The plugging is being performed as part of the pre-rig preparation for upcoming coiled tubing drilling (CTD) operations. The plugging is scheduled to take place the last week of August. The objective of the CTD project is to drill four lateral sidetracks (3A-17A, 3A-17AL1, 3A-17AL2, and 3A-17AL2- 01) targeting the A2 and A3-sands to access reserves west of the parent wellbore, across anorth-west sealing fault. Two laterals each will be drilled from two separate casing exits in the 3.5" liner. Permit to Drill applications for those laterals are being submitted separately. Attached to this Sundry application is an outline of previous and future job operations planned for 3A-17. If you have any questions or require additional information please contact me at my office 907-263-4093 or on my cell phone 907-230-7550. Sincerely, Jill L G~ Coiled Tubing Drilling Engin~eelr Sundry Application for Plug•g Perforations • KRU 3A-17 Well History and Objective Well 3A-17 was originally drilled and completed as an A-sand producing, single completion well in September 1996. The A sands were perforated and fracture stimulated in October/November 1996. Th well operated as an A-only producer until 1999 when the C and B sands were perforated in June of that year. Production from 3A-17 has historically been lower than expected due to poor injection support. The reservoir in the surrounding area is highly faulted and seismic data confirms the current wellbore position is not optimal. The purpose of the CTD project is to drill four CTD sidetracks in the A2 and A3 sands away from the parent wellbore and across faults that are believed to be isolating. The outcome expected is improved sweep efficiency and oil recovery. Perforations in the parent wellbore are planned to be plugged prior to CTD rig arrival however the lateral footage drilled in the immediate vicinity of parent well will recover the existing ~ perforations. Operational Outline ~ Co^ cv~ . ~~~3~t~ d~z~~ Pre-Rig Work Remaining 1. Changeout all gas lift valves to dummy valves and caliper the 3.5" liner below the tubing tail. 2. Set a cast iron bridge plug above the A sand perforations (and below the lower CTD kickoff point). (~e~o}-~.~ ~ 3. Perforate the 3.5" liner across the kickoff point locations ~~ ~- lp lv~~ 7 4. Set the lower whipstock at 7412' MD P 1~~, ~~~~~- i(~;.,;iUvt-~-~°C ~ ~ 5. Cement squeeze the B and C sand perforations, cleaning out to the top of the whipstock ~ ~ ~~ ~ c, ck.,,- 6. Prepare wellsite for rig arrival. Rig Work ~a ~ P~ /L 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 3saa ~' f ` /°~ 2. Lower Window a. Mill a 2.74" window exit with high-side orientation off of the whipstock previously cemented place at 7412' MD b. 3A-17A Lateral i. Drill 2.70" x 3" bi-center lateral in the A2 sand ii. Load well with kill weight fluid. Run 2'/" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 3A-17AL1 lateral c. 3A-17AL1 Lateral i. Drill 2.70" x 3" bi-center lateral in the A3 sand ii. Load well with kill weight fluid. Run 23/" slotted liner with a shorty deployment sleeve on top from TD to just inside the window 3. Upper Window a. Seta 3.5" Monobore whipstock at 7395' MD and mill a 2.74" window exit with high-side orientation off of the whipstock set at 7395' MD b. 3A-17AL2 Lateral i. Drill 2.70" x 3" bi-center lateral in the A2 sand ii. Load well with kill weight fluid. Run 23/" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 3A-17AL2-01 lateral c. 3A-17AL2-01 Lateral i. Drill 2.70" x 3" bi-center lateral in the A3 sand ii. Load well with kill weight fluid. Run 2'/8" slotted liner with a shorty deployment sleeve on top from TD to inside the 3.5" liner above the window. 4. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Handover to Production group. ~~ 8/18/2010 COtIOCOP~'11~~Ip5 11 Attributes ~,, C~~ KUP A1~Sk21, ItiC. Wellbore APVUIM^^ fieiON 5 112 SURFACE, 3`17 821 cAS uFr, 4,236 7y12 3A-17 1!8" BH EJ, RDX chgs, rotate t/8" BH EJ, ROX chgs, PROa/cnor+ asw s~, ~. ~.~ . ~ Page 1 of 1 Schwartz, Guy L (DOA) From: Venhaus, Dan E [Dan.E.Venhaus@conocophillips.com] Sent: Thursday, August 26, 20.10 11:01 AM ~rj~ f ~ L - l 3 ~ To: Schwartz, Guy L (DOA) Cc: Gantt, Lamar L; Schwartz, Guy L; Eller, J Gary; Long, Jill W; Ohlinger, James J Subject: 3A-17 variance Guy, In regards to the 3A-17 sundry request, ConocoPhillips requests a variance from 20 AAC 25.112 (c) which requires a cement plug across and above all perforations to be abandoned in cased hole wells. The proposed plugging procedure for the 3A-17 perforations does meet the overall objective of this section, providing an equally effective plugging of the well to prevent migration of fluids to other hydrocarbon zones or freshwater. Please feel free to contact me should you need any other information. Thanks, Dan Venhaus Wells/CTD Engineer ConocoPhillips AK, Inc. 907-263-4372 office 907-230-0188 cell 8/26/2010 ~~ Page 1 of 2 Schwartz, Guy L (DOA) From: Venhaus, Dan E [Dan.E.Venhaus@conocophillips.com] Sent: Thursday, August 26, 2010 2:04 PM To: Schwartz, Guy L (DOA) Cc: Long, Jill W X71 ' 9 G - /3L Subject: RE: 3A-17 / ~ ~ Guy, 1. Set the bridge plug @ 7450' MD, approximately 24' above the A-sand perfs. 2. Perform ahigh-pressure squeeze on B/C perfs and circulate out contaminated cement down to the whipstock. 3. Let cement cure 72 hrs then slickline tag whipstock and PT squeeze. Let me know if you need anything else. Dan Venhaus Wells/CTD Engineer ConocoPhillips AK, Inc. 907-263-4372 office 907-230-0188 cell From: Schwartz, Guy L (DOA) [mailto:guy.schwariz@alaska.gov] Sent: Thursday, August 26, 2010 11:27 AM To: Venhaus, Dan E Subject: RE: 3A-17 Danny, A couple of questions on the sundry: 1. Where are you setting the the CIBP? 2. Are squeezing the B/C ... then drilling out to the top of the whipstock??. Not clear in the procedure. 3. Are you testing the squeeze before drilling out the the window for the first lateral? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Venhaus, Dan E [mailto:Dan.E.Venhaus@conocophillips.com] Sent: day, August 26, 2010 11:01 AM To: Schwartc, DOA) Cc: Gantt, Lamar L; Sch Guy L; Eller, J Gary; Long, Jill W; Ohlinger, James J Subject: 3A-17 variance Guy, In regards to the 3A-17 sundry request, ConocoPhillips requests a va from 20 AAC 25.112 (c) which requires a cement plug across and above all perforations to be abandoned in hole wells. The proposed plugging procedure for the 3A-17 perforations does meet the overall objective of this s ~on, providing an equally effective plugging of the well to prevent migration of fluids to other hydrocarbon zones or fre ater. Please feel free to contact me should you need any other information. Thanks, 8/26/2010 ' ~ ~ Page 2 of 2 Dan Venhaus Wells/CTD Engineer ConocoPhillips AK, Inc. 907-263-4372 office 907-230-0188 cell 8!26/2010 • • WELL LQG TRA/1 /~"MI TTAL ,,. PaoAcrive Dingnosric SeRVicES, INC. Ta: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 17-Mar-10 2) ~:~ Signed Print Name: LL MAR 2 3 2010 Date .f _ ~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 99518 PNONE: (907)245-8951 FAX: (9071245-88952 E-MAIL : pdsanchorage(aamemorvlog.com WEBSITE : www.memoryloa com 3A-17 1 Report/ EDE 50-029-22691-00 ~~~_~3~ n °~~/~ C:\Documents and Settings\Diane Williams\Desktop\Transmit_Conoco.docx J • • Memory Mul~a-Finger Caliper Log Results Summary Company: ConocoPhiltips Alaska, Inc. Well: 3A-17 Log Date: March 17, 2010 Field: Kuparuk Log No.: 7832 State: Alaska Run No.: 1 API No.: 50-029-22691-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD MOD Top Log Intvl1.: Surface Pipet Use: Tubing and Liner Bot. Log Intvl1.: 7,298 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS ',' This caliper data is tied into the Camco D-Nipple @ 7,247 (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing and liner logged appear to be in good to fair condition, with a ' maximum recorded wall penetration of 25% recorded in a line of pits in joint 142 (4,602')_ Wall penetrations ranging from 20% to 25% wall thickness are recorded in 25 of the 239 joints logged. Recorded damage ' appears as line corrosion, line of pits, and scattered pitting. No significant areas of cross-sectional wall loss are recorded throughout the tubing and liner logged. Deposits restrict the I.D. to 2.56" in joint 221 (7,288'). A graph illustrating minimum recorded diameters on a joint-by joint basis is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Line of pits { 25%) Jt. 142 @ 4,206 Ft. (MD) Line of pits (24%) Jt. 128 @ 4,130 Ft. (MD) Line of pits (24%) Jt. 144 @ 4,686 Ft. {MD) Isolated pitting (24%) Jt. 170 @ 5,539 Ft. (MD) Line corrosion (24%) Jt. 153 @ 4,955 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Minimum I.D. = 2.58 Jt. 221 @ 7,288 Ft. (MD) Deposits Minimum I.D. = 2.58 Jt. 220 @ 7,240 Ft. (MD) Deposits Minimum I.D. = 2.66 Jt. 220.2 @ 7,253 Ft. (MD) No other significant I.D. restrictions are recorded throughout the tubing and liner logged. s ~ ~ ~~, cr F~ ?t~t~t'i Field Engineer: J. Halvorsen Analyst: C. Waldrop Witness: C. Kennedy ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TY, 77497 Phone: (281} ar (888) 565-9085 Fax: (281} 565-1369 E-mail: PDS~,amemorylog.com Prudhoe Bay Field office Phone: (907} 659-2307 Fax: (907} 659-2314 • Correlation of Recorded Damag Pipe 1 3.5 in (25.6' - 7273.2') Well: Field: Company: Country: Survey Date: ;e to Borehole Profile 3A-17 Kuparuk ConocoPhillips Alaska, Inc. USA March 17, 2010 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 54 817 1607 2399 GLM 1 3230 ~ c 4024 y GLM 2 v D 4854 GLM 3 5682 GLM 4 6512 GLM 5 GLM 6 221 72 73 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 221 1 25 ~, 50 75 100 E 125 'o i 150 (, 175 r'7' 200 s • ~~ Minimum Diameter Profile Well: 3A-17 Survey Date: March 17, 2010 Field: Kuparuk Tool: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches 1.69 0.1 3 9 14.1 20 26 32 3S 44 50 56 62 68 74 80 86 91.1 95 101 d 107 ~ 113 Z 119 C 125 ~O 130 134 140 146 152 158 161 167 173 179 185 188 194 200 206 209 215 219 220 Minimum Measured Diameters (in.) 1.94 2.19 2.44 2.69 2.94 __ i ~II LI i ~_ -" i i= I I I I • PDS Report Overview ~-~,..__ ®., Body Region Analysis Well: 3A-17 Survey Date: March 17, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size; 1.69 Country: USA No. of Fingers: 24 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE 8RD MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body _-_ metal loss body 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1 °,/0 10% 20% 40% 85% 85% Number of'oints anal sed total = 239 pene. 12 145 65 17 0 0 loss 140 99 0 0 0 0 Damage Configuration (body ) 50 40 30 20 10 0 isolated general line ring hole/poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 65 49 2 14 0 0 Damage Profile (% wall) ~ penetration body ,__ s?: rnetal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 Bottom of Survey = 221 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 3A-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: March 17, 2010 Joint No. Jt. Depth (Ft.) I'c~n. 111>ce,i (Inti.? Pen. Body (Ins.) P<~n. °~~ Meal Ic~sti °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 26 U 0.02 ') 2.92 PUP .2 29 t) 0.00 I 2.91 PUP .3 39 U 0.01 3 2.90 PUP .4 50 n 0.00 ? +~ 2.93 PUP 1 54 0 0.02 ~i 2.94 2 86 t~ 0.03 tU 2.93 3 118 t) 0.02 ~1 2.92 ~ 4 149 t) 0.01 v I 2.92 5 181 O 0.01 i 1 2.93 6 213 (I 0.02 (> 2.93 7 244 t~ 0.03 tU 2.91 8 27S a .02 ~) 2.93 9 307 a 0.03 1 t) I 2.92 10 339 t~ 0.00 1 1 2.93 11 371 i) 0.03 12 _' 2.93 12 403 t) 0.02 ~~ .'_ 2.93 13 434 t I 0.02 ~) 2 2.94 14 466 t ~ 0.01 ~ 1 2.91 14.1 498 ti 0 0 l) 2.81 Camco DS-Landin Ni le No 0 15 500 (~ 0.01 5 1 2.93 16 531 t) 0.01 ?' ~' 2.92 17 563 (1 0.02 ~) 2.93 18 594 U 0.02 ~~ 2.93 19 626 O 0.03 1 U 5 2.93 20 658 (l 0.01 4 2.93 21 690 t ~ 0.02 ' ~ 2.93 22 721 U 0.02 ~) _' 2.94 23 753 (> 0.01 4 1 2.94 24 785 (~ 0.01 1 2.91 ~ 25 817 (! 0.02 `3 (~ 2.94 ~ 26 849 t~ 0.01 a ~' 2.93 ~ 27 880 ~~ 0.02 ~) ? 2.93 28 912 ~ ~ 0.02 ~) ' 2.93 29 944 U 0.01 4 1 2.94 30 976 U 0.02 9 ? 2.93 31 1008 t 1 0.01 2 ' 2.92 32 1040 C1 0.00 2 1 2.92 33 1071 t) 0.02 `) 2.92 34 1103 t) 0.02 9 2.93 35 1135 ~~ Q01 ? I 2.93 36 1 163 ~) 0.02 ~) I 2.92 37 1195 (~ 0.02 ~> 2.93 38 1227 (1 0.02 '~) 2.94 39 1258 U 0.02 9 1 2.93 40 1290 t) 0.02 9 ? 2.93 41 1322 t) 0.03 1 t? 2.93 42 1354 l) 0.02 ~~ _' 2.93 43 1386 O 0.02 9 y 2.94 44 1417 i ~ 0.01 3 1 2.92 45 1449 (( 0.03 1(l 2.93 _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 3A-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 17, 2010 Joint No. Jt. Depth (FtJ I'~•n. Ulxc~~ (lus.} Pen. Body (Ins.) Pen. %, Mel~rl loss 44, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 46 1481 ~ ? 0.02 ~) 2.93 47 1513 U 0.02 '~) ? 2.94 48 1543 i ? 0.02 ~? ~' 2.94 49 1575 : ~ 0.02 t3 1 2.93 50 1607 a 0.01 ~? I 2.91 51 1639 ~? 0.01 4 2.93 52 1671 ~ i 0.00 I ~ r 2.92 53 1702 ~ ? 0.02 £i I 2.94 54 1733 t? 0.02 2.93 55 1765 I? 0.01 3 ~' 2.89 Lt. De osits. 56 1797 (? 0.01 ~i 2.94 57 1829 t? 0.02 ~) i 2.92 58 1860 [) 0.02 9 2.94 59 1891 t) 0.02 ~> 2.91 60 1923 (? 0.02 6 I 2.96 61 1955 O 0.02 9 ? 2.92 62 1987 U 0.02 9 ? 2.93 63 2018 (? 0.02 9 I 2.93 64 2050 r? 0.03 11 ~~ 2.94 65 2081 ~ ? 0.00 ~' I 2.93 66 2113 !? 0.02 ~? 2.91 67 2145 ?? 0.02 I 2.93 68 2177 t? 0.01 4 I 2.93 69 2208 a 0.03 1 U s 2.93 70 2240 U 0.02 £3 I 2.91 71 2272 U OA2 I 2.93 72 2303 t? 0.02 ~) 2.93 73 2335 t~ 0.01 ; _' 2.93 74 2367 t? 0.02 ~) I 2.93 75 2399 ~) 0.01 5 1 2.92 76 2431 t? 0.02 `? _' 2.91 Lt. De osits. 77 2463 U 0.02 t3 1 2.92 78 2494 t? 0.02 E> I 2.93 79 2526 t? 0.01 4 t? 2.92 80 2558 ~? 0.02 9 _' 2.92 81 2589 (? 0.02 £3 ? 2.92 Lt. De osits. 82 2621 (? 0.01 4 1 2.91 83 2653 U 0.02 8 1 2.91 84 2685 i? 0.03 1U 2.92 85 2 716 ~ ? 0.02 ~ i 2.93 86 2749 ~! 0.01 (", I 2.92 87 2780 ~? 0.03 11 1 2.92 88 2812 U 0.02 ~5 :' 2.92 89 2844 ~? 0.01 2 I 2.92 90 2876 U 0.02 9 ? 2.91 91 2908 t? 0.02 9 ~' 2.94 91.1 2939 U 0.02 ii 2.92 PUP 91.2 2954 (? 0 t) !! N A GLM 1 Latch ~+ 2:30 91.3 2961 U 0.03 11 -t 2.96 PUP 92 2976 ~? 0.02 ~? ~' 2.91 _ Lt. De osits. _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 3A-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 17, 2010 Joint No. Jt. Depth (Ft.) I'c•n. Ul~sc~t (Inti.) Pen. Body (Ins.) Pen. °/> Metal loss 9~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 93 3008 t) 0.01 5 1 2.93 94 3040 i) 0.02 9 ? 2.94 95 3071 i) 0.00 2 O 2.93 96 3103 a 0.02 1 2.93 97 3136 i) 0.02 I 2.91 98 3167 U 0.02 ~a I 2.95 99 3199 U 0.02 ;'~ 2.94 '~ 100 3230 t) 0.02 tt _' 2.93 101 3263 U 0.02 7 1 2.94 102 3294 U 0.02 9 1 2.94 103 3326 U 0.02 8 1 2.93 104 3358 t) 0.02 9 1 2.93 105 3389 O 0.01 2 I 2.92 106 3421 U 0.02 7 I 2.92 107 3452 ~) 0.03 1 t) 2.94 108 3483 U 0.03 1 U I 2.92 109 3516 O 0.02 ~1 ~ 2.93 110 3547 O 0.03 11 ~ 2.93 11 1 3579 t t 0.00 I I 2.91 112 3611 U 0.00 1 O 2.92 113 3643 U 0.00 2 I 2.92 114 3675 t) 0.03 II 2.92 115 3706 U 0.02 ') 2.92 116 3738 U 0.02 't 2.90 117 3770 U 0.02 ~1 ! 2.91 118 3802 U 0.03 1!) I 2.92 119 3833 O 0.00 I 2.90 120 3865 U 0.02 ~~) _' 2.92 121 3897 O 0.02 9 t) 2.91 122 3929 O 0.03 1 U _' 2.92 123 3961 0 0.03 11 I 2.92 124 3992 U 0.05 20 ~' 2.92 Line of its. 125 4024 t) 0.03 1 "~ _' 2.93 Shallow line of its. 126 4056 t) 0.02 9 1 2.92 127 4088 (? 0.04 I i 1 2.93 Shallow line of its. 128 4119 ~? 0.06 24 2 2.93 Line of its. 129 4151 ~? 0.05 ZU ? 2.92 Line of its. 130 4183 i) 0.04 1-1 . 2.91 Shallow line of its. 130.1 4215 U 0.04 1 ~~ -{ 2.93 PUP Shallow line of its. - 130.2 4230 !} 0 i) i? N A GLM 2 Latch @ 3:30 130.3 4236 i) 0.04 15 1 2.93 PUP Shallow line of its. 131 4251 t) 0.05 ZU I 2.92 Line of its. 132 4283 U 0.03 I <' I 2.93 133 4314 i) 0.05 pit 2.92 Shallow ittin " 134 4346 i) 0.05 ~1 ; 2.91 Line corrosion. 135 4378 c? 0.06 ~' ~ Z 2.91 Line corrosion. Lt. De osits. - 13G 4409 t) 0.06 23 ~' 2.92 Line corrosion. - 137 4440 O 0.05 19 ~' 2.91 Shallow line of its. 138 4472 ~) 0.06 21 ~' 2.92 Line corrosion. 139 4504 U 0.0 1 ti i 2.92 Shallow line of its. _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 3A-17 Body Wall: 0.254 in Eield: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 17, 2010 Joint No. Jt. Depth (Et.) I'c~n. Ulxe~t (Ins.) Pen. Body (Ins.) !'en. °~, Mcl,rl Loss °'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 140 4536 U 0.04 17 1 2.91 Shallow line corrosion. 141 4567 fr 0.04 f 7 I 2.92 Shallow line of its. 142 4599 U QO6 25 2 2.91 Line of its. 143 4631 (t 0.03 1:3 I 2.91 Shallow line of its. 144 4663 U 0.06 24 1 2.91 Line of its. 145 4695 U 0.04 1 1 2.91 Shallow line of its. Lt De sits. 146 4727 (~ 0.06 22 I 2.91 Line corrosion. _ 147 4759 t) 0.04 17 1 2.91 Shallow line of its. 148 4790 (! 0.04 i 4 I 2.92 Shallow line of its. 149 4822 U 0.04 16 I 2.90 Shallow line of its. 150 4854 (r 0.04 1 5 I 2.88 Shallow line of its. Lt. De osits. 151 4886 U 0.05 1 ~) _' 2.91 Shallow line corrosion. Lt. De sits. 152 4918 0 0.06 12 ~ 2.90 Line corrosion. 153 4949 O 0.06 24 _' 2.90 Line corrosion. Lt. De osits. 154 4981 t) 0.05 ~'(1 1 2.90 Shallow line of its. Lt Dc osits. 155 5013 U 0.04 I ~ I 2.91 Shallow line of its. Lt. De osits. 156 5045 U 0.05 21 2.77 Line of its. De osits. 157 5076 (~ 0.04 15 1 2.89 Shallow line of its. Ia. De osits. 158 5108 t~ 0.06 Z4 2 2.90 Corrosion. Lt. De osi 159 5140 a 0.06 22 ~' 2.90 Line of its. 160 5171 t) 0.06 Z2 Z 2.91 Corrosion. 161 5203 U 0.05 ZU 1 2.90 Shallow line of its. Lt De osits. 161.1 5235 U 0.05 19 2 2.90 PUP Shallow line of its. 161.2 5249 U 0 0 i) N A GLM 3 Latch @ 7:00 161.3 5256 U 0.05 19 i 2.88 PUP Shallow line corrosion. Lt. De osits. 162 5271 U 0.03 10 ? 2.90 Lt. De osits. 163 5303 i) 0.05 2t) ~i 2.91 Isolated ittin Lt De osits- 164 5334 it 0.03 11 I 2.91 Lt. De osits. 165 5366 i) 0.04 I i 1 2.91 Shallow ittin . 166 5397 U 0.03 11 1 2.90 Lt De osits. 167 5430 O 0.02 9 1 2.90 Lt. De osits. 168 5461 t) 0.03 11 1 2.90 Lt De osits. 169 5493 U 0.04 15 I 2.91 Shallow ittin Lt. De osits. 170 5525 U 0.06 24 I 2.91 Isolated ittin Lt. De osits. 171 5557 O 0.04 17 I 2.90 Shallow ittin Lt. De osits. 172 5589 O 0.04 14 1 2.90 Shallow ittin Lt De sits. 173 5619 (~ 0.05 18 1 2.92 Shallow ittin Lt. De osits. 174 5651 I~ 0.04 i 7 I 2.91 Shallow ittin Lt. De osits. 175 5682 (~ 0.06 Z2 I 2.89 Isolated ittin Lt. De osits. 176 5714 (+ 0.04 1' 1 2.90 Shallow ittin Lt. De osits. 177 5745 U 0.03 13 1 2.92 Shallow ittin . 178 5777 (7 0.04 16 1 2.91 Shallow line corrosion. 179 5809 (~ 0.05 Zt) 1 2.90 Line corrosion. 180 5841 l) 0.04 15 1 2.90 Shallow ittin . 181 5872 U 0.04 1 i 1 2.89 Shallow ittin Lt De osits. 182 5904 U 0.05 18 1 2.90 Shallow ittin Lt De osits. 183 5937 t) 0.06 22 I 2.91 Isolated ittin . 184 5968 U 0.04 1 h I 2.92 Shallow ittin . 185 5999 ++ 0.04 1 i 2.90 Shallow line corrosion. Lt De osits. 186 6031 ~1 0.04 la 1 2.91 Shallow ittin Lt.De osits. _ Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE SKD MOD Well: 3A-1 7 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 17, 2010 Joint No. Jt. Depth (Ft.) P~~n. U)~se~t (Ins.) Pen. Body (Ins.) Pc~n. % Mclal loss "~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 187 6063 (? 0.02 ~) I 2.92 187.1 6094 t! 0.03 1 1 ? 2.89 PUP Lt. De osits. 187.2 6110 tr 0 t) t) N A GLM 4 Latch @ 2:30 187.3 6116 t! 0.04 l~ 2.92 PUP Shallow ittin . 188 6132 U 0.02 8 It 2.88 Lt De osits. 189 6164 l) Q_03 1 1 u 2.90 Lt De osits. 190 6195 tl 0.04 16 I 2.90 Shallow ittin Lt. De osits. 191 6227 l) 0.03 1 "~ I 2.88 Lt. e osits. 192 6259 t) 0.05 1 ~) I 2.88 Shallow ittin Lt. De sits. 193 6290 U 0.03 11 t) 2.89 Lt. De osits. 194 6322 U 0.00 1 U 2.90 Lt. De osits. 195 6354 O 0.02 7 U 2.88 Lt De osits. 196 6386 (1 0.01 6 !) 2.90 Lt De osits. 197 641 7 U 0.02 C> 1 2.89 Lt De osi ts. 198 6449 (! 0.02 t) !% 2.89 LL De osits. 199 6481 t) 0.03 1 1 I 2.91 Lt. De osi ts. 200 6512 U 0.02 ~) I 2.90 Lt. De osits. 201 6544 O 0.02 ~? t! 2.89 Lt. De osits. 202 6576 U 0.02 ~) I 2.89 Lt De osits. 203 6607 U 0.00 1 t! 2.88 Lt De osits. 204 6639 t? 0.03 1 U I 2.90 Lt De osits. 205 6671 U 0 0 t! 2.84 Lt. De osits. 206 6702 U 0.02 9 t) 2.88 Lt De osits. 206.1 6734 '1 0.03 11) ' 2.92 PUP 206.2 6749 U 0 U t. N A GLM 5 Latch ~ 1:30 206.3 6754 ;? 0.02 4 I 2.91 PUP 207 6770 t! 0.01 5 ~? 2.87 Lt. De osits. 208 6801 t) 0.04 15 I 2.88 Shallow ittin Lt. De osi is. 209 6832 (? 0.01 6 U 2.88 Lt De osits. 210 6864 U 0.02 8 1 2.90 Lt. De osits. 211 6896 U 0.01 2 t) 2.89 Lt. De osits. 212 692 7 O 0.02 9 i 2.91 213 6958 l1 0.00 1 O 2.90 Lt De osits. 214 6991 U 0.01 i i! 2.91 Lt. De osits. 215 7022 (! 0.02 ~) i1 2.89 Lt. De osits. 216 7054 (1 0.00 ? t) 2.86 Lt De osit~. ° 217 7085 (! 0.02 9 O 2.89 Lt De osits. 218 7117 U 0 0 c) 2.88 Lt. De osits. 219 7146 U 0.01 6 (1 2.85 Lt. De osits. 219.1 7178 (! 0.01 i O 2.81 PUP Lt De osits. 219.2 7193 O 0 t) t) N A GLM 6 Latch @ 12:30 219.3 7200 1? 0.03 I ? 2.91 PUP Shallow line corrosion. Lt. De osits. 220 7215 !? 0.03 11 t? 2.58 De osits. 220.1 7247 t) 0 U 2.75 Camco D-Ni le No Go 220.2 7249 l) 0 t) a 2.66 PUP De osits. 220.3 7254 t) 0 U t? 4.00 Baker 5x4 PBR w X-Over to 3.5" and Locator 220.4 7265 t) 0 l) U 2.99 3.5" Tubin Tail 220.5 7268 U 0 U t) 2.75 PUP Lt De osits. 221 7273 O 0 0 O 2.58 De osits. _ Penetration Body Metal Loss Body Page 5 ~r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r ~ ~ ~ PDS Report Cross Sections ~~ „ Well: 3A-17 Survey Date: March 17, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 ~ f L-80 EUE 8RD MOD Anal st: _ _ C. Waldrop Cross Section for Joint 142 at depth 4602.14 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 99 Tool deviation = 39 ° Finger 7 Penetration = 0.064 ins Line of pits 0.06 ins = 25% Wall Penetration HIGH SIDE = UP • • Goss Sections page 1 PDS Report Cross Sections Well: 3A-17 Survey Date: March 17, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 EUE 8RD MOD Analyst: C. Waldrop Cross Section for Joint 128 at depth 4129.59 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 99 Tool deviation = 40 ° Finger 20 Penetration = 0.062 ins Line of pits 0.06 ins = 24% Wall Penetration HIGf I SIDE = UP • • Cross Sections page 2 PDS Report Cross Sections Well: 3A-17 Survey Date: March 17, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EUE 8RD MOD Anal st: C. Waldro Cross Section for Joint 221 at depth 7288.22 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 Tool deviation = 41 ° Finger 21 Projection = -0.324 ins Deposits Minimum I.D. = 2.58 ins HIGH SIDE = UP • Cross Sections page 3 PDS Report Cross Sections Well: 3A-17 Survey Date: March 17, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EUE 8RD MOD Anal st: C. Waldrop. Cross Section for Joint 220 at depth 7239.87 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 Tool deviation = 40 ° Finger 19 Projection = -0.362 ins Deposits Minimum I.D. = 2.58 ins HIGH 51DE = UP • Cross Sections page 4 ~, ~~~ KUP ,~ 3A-17 ConocoPhiltip s I II Attributes An le 8 1111p TD AI, ~ ~,.,, ~ ~. ~ W e8bore APW WI Fldd Name 500292269100 KUPARUK RIVER UNIT W dl Status Ind l°) ND gIKB) PROD 42.99 5,633.60 AU Btm (RI(B) 7.784.0 CommerR N251ppm) Date FSSV: NIPPLE 220 3!15!2009 Las[ tatlan tlDate KB-Crd (R) WO Rlg Release Dale 9!2/1996 well con - A-n 173 07 01o e.l rbs Abt -- -- : Sch merit- ual Amotatlan Last Tag: SLM ) 7.468.0 Entl Dale Amotatlan Last Mod By 1/30/2010 Rev Reason: TAG Imosbor E11d Dale 1/30/2010 Casio Strin s Casing Desulptlon String O Ilnl D String ID IIn1 7oP f~Bl Se[ Depd1 f~Bl Se[ Dep[h (TVD) Irocel Stung Wt (lbsflq Stdrg Grade StMg Tap T11rd I CONDUCTOR 1 6 15.062 0.0 121.0 121.0 62.50 H-40 colvDUCroR 12i SURFACE 75 /8 6.750 0.0 3,821.0 3,307.8 29.70 L-80 PRODUCTION 51 /2 4.825 0.0 7.266.0 5,930.7 15.50 L-80 LINER 31 12 2.992 7,266.0 7,782.0 6,333.3 9.30 L-80 Tubin Strln s NIPPLE. 506 Turing Desatptlon SfnINJ O Iinl D Stnng lO Pnl Top (rote) Set De pth pIKB) setoepm ) (R1CB) sdrgWt Iros/It) song r+ade Strhg Tap 7nrtl TUBING 3 1/ 2 2.992 0.0 7,268.0 5.932.2 9.30 L-80 EUE 8RD MOD Ottter In Hole All Jewe l .Tubin Run 8 Retrievabl Fish etc. GAS LIFT 295i Top (RKB) Top Depth INDI I~BI Top Md (°) Descrlptlon Comment Rtn Date ID IIn) 504 504.0 0.87 N IPPLE Camco'DS' Landing Nipple NO GO 9/14/1996 2812 2,957 2,650.6 39.20 G AS LIFT BST/AXT/1/GLVIf-1/.156/1303! Comment: STA 1 11/30/1996 3.000 suRFACE. 4,231 3,625.8 40.50 G AS LIFT BST/AXT/1/DMY(f-1/// Comment: STA 2 9/14!1996 3.000 3,e21 5,250 4,398.4 41.22 G AS LIFT BST/AXT/1/GLV/T-11.156/1335/Comment:5 A3 11f30/1996 3.000 6,110 5,037.1 40.94 G AS LIFT BST/AXT/1/DMY(f-1/// Comment STA 4 9/14/1996 3.000 6,749 5,527.6 39.12 G AS LIFT BSTIAXT/1/OV/T-1/.188// Comment: STA 5 2/612007 3.000 GAS LIFT. 6 231 7,194 5,874.3 38.46 G AS LIFT BST/AXT/1/DMYlf-1 /// Comment: STA 6 2/4/2007 3.000 7,247 5,915.8 38.38 N IPPLE Camco'D' Nipple NO GO; Pugetl Spartek gauges end shut in too! from "d' nipple 3/20!99. 9!14!1996 2.750 7,254 5,921.3 38.37 L OCATOR BAKER BGH-22 LOCATOR W/10' SEALS 9/14/1996 3.500 7,254 5.921.3 38.37 P BR BAKER 5X4 PBR W/XO TO 3.5" AND LOCATOR 9/14!1996 4.000 GAS LIFT 5,250 7.268 5,932.2 38.34 T TL 9/14/1996 2.992 Perforations & Slots Top IroCB) Blm lrtl®) Top ITVD) MKB) BIm ITVD) (ro(B) Zone Date snot Dens Ish-- Typo Comment GAS LIFT, 6.110 7,347 7,370 5,995.2 6,013.1 CA, 3A-17 6/4/1999 2.0 APERF Alternate 2 1/8" Power EJ, HMX chgs wf21l8' BH EJ. RDX ch s rotate 90 9 ' deglrepeat 7,380 7,390 6,020.9 6,028.7 UNIT B, 3A-17 6/4/1999 2.0 APERF Abemate 2 1/8" Power EJ, HMX chgs w/2 1/8" BH EJ. RDX chgs, rotate 90 deg/repeat oas LIFT. 6,749 7,474 7,504 6,093.9 6.117.3 A-3, 3A-17 10/29/1996 2.0 IPERF 180 deg, phasing; 2 1/2" HC Notes: General & Saf Fstl Date Amotatlan 7/27/2003 NOTE: POSSIBLE FISH @ 4231' RKB; COIL STUCK. BUT PULLED FREE. 7/28/2003 NOTE: CIB TAGGED OBSTRUCTION @ 5250'; MULTIPLE DEEP GOUGES GAS LIFT, 7/9!2005 NOTE: TAGGED OBSTRUCTION @ 5250 7,199 8/25/2005 NOTE: PHANTOM OBSTRUCTION STILL FLOATING DOWNHOLE NIPPLE. 124] LOCATOR, T,254 PBP., 7254 PRODUCTION. 1,266 rn-. 7 2se PPERF 7 34]-7 370 APERF, 73so-73so IPERF, 7 474-7$06 LIMER, 7 ]82 TD, 7,/84 ~~ 7 • ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • APR ~~ ~ ~?;y t~ChO€~~ April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~' ~o,, ~ ~ ~~ ,1 `~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 27th and 30th, 2009. The corrosion inhibitor/sealant was pumped April 6th and 15th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry K` lein~ ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 4/17/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-03B 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 ~ 185-237 16' 2.50 25" 3/27/2009 5.95 4/6/2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6!2009 3A-14 185-282 13' 3.00 20" 3/30/2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 09/15/06 Scblumberger RECEIVEr::; NO. 3959 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SEP 1 5 2006 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ Oil & Gas Cons. Coffi!ì'~JCta Anchcrnge ,r,/).t\.'MEX;, :~'\I~~i.:~' Kuparuk lL1(o - (3d- 2f,n\'- í' i Q J\.\lJ Str J ~, ~ Field: Well Job# Log Description Date BL Color CD 2A-18 11213804 LDL 09/09/06 1 1A-20 11213802 PROD PROFILE W/DEFT 09/07/06 1 3A-17 11213803 PROD PROFILE W/DEFT 09/08/06 1 1J-156 11415621 PRODUCTION PROFILE 09/06/06 1 2A-13 11415619 PRODUCTION PROFILE 09/04/06 1 1 L-28 11213805 PROD PROFILE W/DEFT 09/10/06 1 1 L-1 0 1142164 INJECTION PROFILE 09/09/06 1 1 J-1 02 11421625 US IT 09/11/06 1 2E-05 N/A INJECTION PROFILE 09/07/06 1 2E-05 11216326 sBHP 09/06/06 1 2U-03 11213007 INJECTION PROFILE 09/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317, Thank you. . . oN OR BeFORE p_L_ ~~L U ~o~ C:LO-B, lXt~I:LM.D OC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing Alter casing Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 41' RKB, 41' Pad 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service ~. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 663' FSL, 785' FEL, Sec 7, T12N, R9E, UM 3A-17 At top of productive interval: 9. Permit number/approval number: 1042' FNL, 2627' FEL, Sec 17, T12N, R9E, UM 96-132 At effective depth: 10. APl number: 1110' FNL, 2389' FEL, Sec 17, T12N, R9E, UM 50-103-22691-00 At total depth: 11. Field/Pool: 1150' FNL, 2372' FEL, Sec 17, T12N, R9E, UM Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 7785 feet Plugs (measured) None tiue vertical 6336 feet Effective Depfl measured 7717 feet Junk (measured) None true vertical 8283 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 212 Sx AS I 121' 121' Surface 3780' 7.625" 1020 Sx AS III & 3821' 3309' 340 Sx Class G Production 7227' 5" 190 Sx Class G 7266' 5931' Liner 516' ' 3.5" Included in above 7782' 6333' Perforation Depth measured 7347'-7370'; 7380'-7390'; 7474'-7504' true vertical 5994'-6012'; 6020'-6028'; 6093'-6117' Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, L-80 @ 7268' 0 0"t- Packers and SSSV (type and measured depth) A~-~I,,,' 0il ¢¢ Pkr: Baker GBH-22 PBR @ 7254'; SSSV: None, nipple @ 504' Anchorage 13. Stimulation or cement squeeze summary Perforate 'B&C' sands on 6/4/99. Intervals treated (measured) 7347'-7370'; 7380'-7390' Treatment description including volumes used and final pressure !:-'"' ~-~-.~ Perforated using 2-1/8" EJ guns wi BH & Powerjet charges @ 2 spt, final pressure was 250 psi.~ ~ 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 276 290 90 839 147 Both sands Subsequent to operation 292 276 124 .883 150 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢~7/~ Title'. Production Engineering Supervisor Date Form 10-404 15/88 SUBMIT IN DUPLICATE ~CO Alaska, Inc. WELL 3A-17 DATE 06/04/99 DAY 1 FIELD ESTIMATE KUPARUK RIVER UNIT ELL SERVICE REPORT 3A-17(4-1)) JOB SCOPE JOB NUMBER P ERFORATIONS-E-LINE 0601991513.5 DALLY WORK INITIAL C SAND PERF OPERATION COMPLETE I SUCCESSFUL O Yes ~ No I O Yes ~ No AFC# ICC# I DAILY COST K85174 230DS36AL $17,371 Initial Tbg IFinalTbg I Initial IA I 250 PSll250 PSII900 PSI I IKEY PERSON SWS-ELMORE ACCUM COST $18,957 Final IA Initial CA I Final CA ITTL Size 900 PSI 425 PSII 425 PSII 3.500 " UNIT NUMBER 2128 SUPERVISOR SCHUDEL Signed JMin ID I Depth 2.750" 7247 FT DALLY SUMMARY PERFORATED 7347''7370' & 7380''7390,' 4 SPF'180 PHASED' +/- 90 DEG FLSH' ALTERNATING BIG HOLE/POWER-JET DEEP PENETRATING ENERJET CHARGES. TIME LOG ENTRY- 07:45 MIRU SWS 2128 ELMORE. TGSM. RU. RETIE WEAKPOINT TO 7/3 TO MAXIMIZE WEAKPOINT STRENGTH. PT 3000#. 10:00 RIH W/SWIVEL,CCL,MPD, 2 1/8" X 10' ENERJET GUN, 2 SPF, ALTERNATING BIG HOLE/POWER JET CHARGES, OFFSET 90 DEG LEFT LSH. OAL-26.8' 11:15 TI TO SWS SLTJ, CORRECT -9', RIH TO 7450'. 11:20 LU TIE IN PASS.RIH TO 7450'. 11:35 LU TO SHOOT 7380'-7390', 2 SPF GUN 1. GOOD SHOT INDICATION, STUCK AFTER SHOOTING, HADX TO PULL UP TO 1600# SHARPLY TO FREE. POOH. ENGINEER LEAVING LOCATION TO GO TO 1C-23 TO DISARM & RD GUN THAT WAS FISHED. PUH TO 200' AND STANDBY. 14:00 ELMORE BACK FROM 1C-23. POOH AND RD GUN 1. 14:45 RIH W/GUN 2...SAME AS GUN I EXCEPT ORIENTED 90 DEG RIGHT FROM LSH. 15:30 LU CHECK TI. RIH TO 7450'. 15:35 SHOOT GUN 2. NO PULLS AFTER FIRING. POOH. 16:30 RIH W/GUN 3, 23' ORIENT RIGHT 90 DEG LSH. OAL=40' 16:50 LU CHECK TI. RIH TO 7450' 16:55 SHOOT GUN 3 7347'-7370' RIGHT ORIENTATION. POOH. 17:45 RIH W/GUN 4, 23' ORIENT LEFT. 18:10 CHECK TI. RIH 9420'. 18:15 LU TO SHOOT 7347'-7370', ORIENTED 90 DEG LEFT FROM LSH. GOOD SHOT INDICATION. PULLED 1700#, BUT CAME FREE. POOH. 19:00 AT SURFACE, BD LUB, RD. RELEASE RADIO SILENCE. 19:40 RDMO TO HOUSE. · SERVICE COMPANY- SERVICE DAILY COST ACCUM TOTAL $0.00 $21.00 ARCO $164.00 $164.00 HALLIBURTON $0.00 $1,115.001 LITTLE RED $330.00 $780.00 SCHLUMBERGER $16,877.00 $16,877.00 TOTAL FIELD ESTIMATE $17,371.00 $18,957.00 'PERMIT AOG~ Individual Well Geological Materials Inventory DATA T DATA PLUS .......................................... Page: 1 Date: 09/15/98 RUN RECVD 96-132 CBL L~/7150-7698 FINAL 11/08/96 96-132 ALPC5 --L'~3833-7784 96-132 96-132 ADN ~.~f/3833-7784 7541 ~SCHLUM ARC5/ADN4 Are dry ditch samples required? yes ~~d received? Was the well cored? yes ~~alysis & description received? Are well tests required? ~s ~/Received?, ~~no Well is in compliance Initial CO~ENTS FINAL 12/06/96 FINAL 12/06/96 1 12/06/96 ye s---T~---~ ARCO Al[Ska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 6, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3A- 17 (Permit No. 96-132) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3A-17. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad STATE OF ALASKA ' ' ALASK,. OIL AND GAS CONSERVATION C,JMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1'. '~tat~J~ of V~ell ............ ClaSsification of Service Well ' ' [] Oil iq Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-132 3. Address .... 8. APl Number ..... P. O. Box 100360, Anchorage, AK 99510-0360 ¢': ;':- .~ .... ~ 50-029-22691 ...................... 4. Location ofwell at surface ¢ ,.,~..~7.._~_~',,~ 9. Unit or Lease Name 663' FSL, 785' FEL, Sec. 7, T12N, RDE, UM ,!" ?;~i:;?.;;~:;;?!'iii:;ii~'~ ~___,r~~..: Kuparuk River Unit At top of productive interval ;~;l~,~i' ; 10. Well Number 1042' FNL, 2627' FEL, Sec. 17, T12, RDE, UM ~ 3A-17 Attotal depth ! ._.~.~;:.r~ i 11. Field and Pool 1150' FNL, 2372' FEL Sec. 17, T12N, RDE, UM .......................... -~ Kuparuk River '5-~---~leVat-ion in feet (indiCate KB, DF, etc.) 16. Lease Designation and Se~:ial I~o. ' ..... Rig RKB 41', Pad 41'I ADL 25632, ALK 2565 i12. Date Spudded 113. DateT. D. Reached 114. Date Comp., Susp., or Aband.j15. Water depth, ifoffshore Ji6. No. of Completions 8/26/96 i 8/31/96111°/29/96 N/A MSLI One 17:"~'otal Depth (MD+TVD) i 18. Plu~' Back Depth (MD+TVD)I'~ 9. DireCtional SurVeyl20. I~Pth Where SSSV set~21. Thickness of Permafrost ............ _7'___7___8_5 ....... 6336 _FT~ 7717 6283 Fq I~Yes I-INo i N/A MD! 1465'(Approx.) 22. Type Electric or Other Logs Run ARC5/ADN/GR, GR/CCL/SLTJ 23. CASING, LINER AND CEMENTING RECORD C,~ING SETTING DEPTH "HOLE .... . SIZE _V~'___.__PER __FT. _ G _R,~:)_. E .... TOP Do'I-roM_, S!ZE I .C_E_MENT!NG REOORB 16" 62.5¢ H-40 SURF. 121' 24" 212 sx AS I 7-5/8" 29.7¢ L~80 SURF. 3821' 9.875" 1020 sx AS III, 340 sx Class G "-~:-~%-;~-"-' - i5:~5~¢-/~:'3-¢¢ ....... [:i~-0 ........ SURF: ........ 77~2' ..... ~;-7~" .... ~--§O ~x---O-I-~-~ G 24. Perforations open to production (MdYTVD o:f i'0P and BottOm 25. ' TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 7268' MD TVD MD TVD 7474'-7504' 6093'-6117' 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL. (U.d) I -- AMOUNT..& KIND OF MATERIAL UsED I 7474'-7504' 198,000# prop in perfs, 12239# prop left in well bore. .......... 27. PRODUCTION TEST iDate First Production iMethod of Operation (Flowing, gas lift, etc.i ................. , 11/12/96 j Flowing Date of Test iHours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE i'~-~-(~i~--F~'~:l:i~ .............. 11/25/96i 17.9 TEST PERIOD° 955 1507 63 0 i 1577 Flow Tul:)i~-~i~-~s-in~--~-~'-~r~ 0,ALCULATED · O¥1-L-~B~ ............. G~-(~F ..........WATER-DEL C)i~- OR~,-~i-i':Y--,~,-~-~-((~-I~i ............................... Press. 2011 1386 24-HOUR RATE. .. 1281 2020 84 =24° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~.~: ,~., '.~: .'~ ,.. ;:;-. .. · ,o; "~i /_'~;!; ~, . . Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markr Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 7342' 5990' Total Pump Volumes for this event: Bottom Kuparuk C 7380' 6020' Category 1. 13220 Top Kuparuk A 7456' 6079' Category 2. 100 Bottom Kuparuk A 7618' 6206' Category 3. 0 Total: 13320 Total to Date: 13320 FREEZE PROTECTED ANNULUS 31. List of AttaChments ........ Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the forego~iqg is true and correct to the best of my knowledge Signed ~-?¢,.),.~..~ _~.~. ............. -_r ~ Title '~I~U¢_~ 6t~l~< Date l't--I6 ['~ 6, Prepared By Name/Number: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 11/7/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3A-17 RIG'PARKER 245 WELL ID: AK8605 TYPE: -- AFC: AK8605 AFC EST/UL:$ 1260M/ 1510M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK' SPUD: START COMP: FINAL: WI' 55% SECURITY:0 API NUMBER' 50-029-22691-00 08/13/96 (D 1) TD: 121'( 0) SUPV:DCL DAILY:$ 08/14/96 (D 2) TD' 121'( 0) SUPV:DCL DAILY:$ 08/15/96 (D 3) TD: 121'( 0) SUPV:DCL DAILY:$ 08/16/96 (D 4) TD: 121' ( 0) SUPV' DCL DAILY: $ 08/17/96 (D 5) TD' 121'( 0) SUPV'DCL DAILY:$ 08/18/96 (D 6) TD' 121' ( 0) SUPV' DCL DAILY-$ 08/19/96 (D 7) TD: 121'( 0) SUPV:DCL DAILY'$ 08/20/96 (D 8) TO: 121'( 0) SUPV:RLM DAILY:$ 08/21/96 (D 9) TD. 121' ( 0) S UPV' RLM DAILY: $ 08/22/96 (D 10) TD: 121' ( 0) S UPV' RLM DAILY'$ MW: 0 0 VISC: MOVE RIG - 1.8 MI F/3F Move rig from 3G-pad. 45,861 CUM:$ 45,861 ETD:$ 0 PV/YP: 0/ 0 APIWL: 0.0 0 EFC:$ 1,305,861 MW- 0 0 rISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG Continue to move rig from 3G pad to 3A pad 45,861 CUM:$ 91,722 ETD'$ 0 EFC:$ 1,351,722 MW: 0 0 rISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG - 0.3 MI F/3F Continue to move rig from 3G pad to 3A pad 46,611 CUM:$ 138,333 ETD:$ 0 EFC:$ 1,398,333 MW' 0 0 VISC: 0 PV/YP' 0/ 0 APIWL: MOVE RIG - .5 MI PAST 3F Continue to move rig from 3G pad to 3A pad 46,747 CUM:$ 185,080 ETD-$ 0 EFC:$ 1,445,080 0.0 MW: 0 0 VISC: 0 PV/YP: 0/ 0 APIWL: MOVE RIG - 0.9 MI F/3B Continue to move rig from 3G pad to 3A pad 46,172 CUM:$ 231,252 ETD:$ 0 EFC:$ 1,491,252 0 0 MW: 0 0 V!SC: 0 PV/YP: 0/ 0 APIWL: 0 0 HAT ROAD LEAVING 3B Continue to move rmg from 3G pad to 3A pad 46,172 CUM:$ 277,424 ETD:$ 0 EFC:$ 1,537,424 MW: 0 0 VISC: 0 PV/YP: 0/ 0 APIWL: LOCATED AT THE 3A/CPF3 "Y" Continue to move rzg from 3G pad to 3A pad 45,411 CUM:$ 322,835 ETD:$ 0 EFC:$ 1,582,835 0 0 MW: 0.0 rISC: 0 PV/YP: 0/ 0 APIWL: 0 0 PULLING MATS UNDER RIG Continue to move rmg from 3G pad to 3A pad 46,196 CUM'$ 369,031 ETD:$ 0 EFC:$ 1,629,031 MW. 0.0 VISC. 0 PV/YP. 0/ 0 APIWL: 0 0 MOVE RIG Continue to move r~g from 3G pad to 3A pad 46,150 CUM:$ 415,181 ETD'$ 0 EFC:$ 1,675,181 MW- 0.0 vise' 0 PV/YP' 0/ 0 APIWL: DRILL MOD OVER 3A-17 Continue to move rmg from 3G pad to 3A pad 49,969 CUM'$ 465,150 ETD'$ 0 EFC'$ 1,725,150 0 0 · Date: 11/7/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/23/96 (D 11) TD: 121'( 0) SUPV:RLM DAILY:$ 08/24/96 (D 12) TD: 121'( 0) SUPV:RLM DAILY:$ 08/25/96 (D 13) TD: 916' ( 795} S UP V: RLM DAILY:$ 08/26/96 (D 14) TD: 3727' (2811) SUPV: RLM DAILY:$ 08/27/96 (D 15) TD: 3833' (106) S UP V: RLM DAILY:$ 08/28/96 (D 16) TD: 3833' ( 0) SUPV: RLM DAILY: $ 08/29/96 (D 17) TD: 5996' (2163) SUPV: RLM DAILY:$ 08/30/96 (D 18) TD: 7376' (1380) SUPV: RLM DAILY:$ MW: 0.0 rISC: 0 PV/YP: 0/ 0 APIWL: 0.0 LAY MATS & PLYWOOD 3F --> 3B Jack rig floor and set down module. Move utility module to 3F pad. 49,903 CUM:$ 515,053 ETD:$ 0 EFC:$ 1,775,053 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 +/- 1.0 MILE FROM 3A-17 Continue to move utility module to 3A pad. 49,059 CUM:$ 564,112 ETD:$ 0 EFC:$ 1,824,112 MW: 8.6 rISC: 88 PV/YP: 26/37 APIWL: 9.5 DRILLING @ 916' Accept rig at 11:30 hrs. 8/25/96. Nipple up diverter. Held team meeting. Function test diverter. 70,196 CUM:$ 634,308 ETD:$ 0 EFC:$ 1,894,308 MW: 9.2 rISC: 60 PV/YP: 26/25 APIWL: 6.4 WIPE HOLE TO HWDP Held team meeting, pre-spud. Directional drill and gyro survey from 121' to 3727' 90,740 CUM:$ 725,048 ETD:$ 0 EFC:$ 1,985,048 MW: 9.2 VISC: 54 PV/YP: 19/23 APIWL: 6.8 LIFT DIVERTER Directional drill from 3727 to 3833' Run 7-5/8" casing to 3821' Cement casing. CIP at 2211 hrs. 8/27/96. 112,327 CUM:$ 837,375 ETD:$ 0 EFC:$ 2,097,375 MW: 8.5 VISC: 29 PV/YP: 2/ 1 APIWL: 20.0 DRILLING Pick up diverter and hang off. Could not raise or lower casing collar out of emergency slip profile. Cut 1' section out of conductor and weld conductor back together. Land 7-5/8" casing on emergency slips with 200K. Set down diverter and lay down landing joint. NU 13-5/8" BOPE. Test all rams, hydril, lines and valves to 300/3000 psi. Drill cement from 3548' to 3713' Test casing to 2000 psi for 30 minutes. 93,426 CUM:$ 930,801 ETD:$ 0 EFC:$ 2,190,801 MW: 9.0 VISC: 36 PV/YP: 7/ 7 APIWL: 8.8 DRILLING AT 6300' Drill cement from 3713, float collar, cement to 3820 and float shoe at 3821' . Drill 10' new hole from 3833 to 3843. Perform LOT. Drill from 3843 to 3863' Perform LOT. Directional drill from 3863' to 5996' Hole packed off. Worked pipe and regained circ. 78,766 CUH:$ 1,009,567 ETD:$ 0 EFC:$ 2,269,567 MW: 11.0 rISC: 44 PV/YP: 20/15 APIWL: 6.2 DRILLING Directional drill from 5996' to 7376' Lost Anadrill signal. Check equipment. 96,205 CUM:$ 1,105,772 ETD:$ 0 EFC:$ 2,365,772 Date: 11/7/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 08/31/96 (D 19} TD: 7785' (409) SUPV: RLM DAILY:$ MW: 11.0 VISC: 47 PV/YP: 20/15 APIWL: 4.2 CIRCULATE AT SHOE Directional drill form 7376' to 7347' Repeat 60' section for Anadrill. Rig up to run casing. Held pre-job safety meeting. Running 3.5" casing. 74,755 CUM:$ 1,180,527 ETD:$ 0 EFC:$ 2,440,527 09/01/96 (D 20) TD: 7785' ( 0) S UP V: RLM DAILY:$ MW: 8.4 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RUNNING COMPLETION Continue to run 3.5" and 5.5" casing to 7782' Pump cement. Cement casing. CIP at 1700 hrs. 9/1/96. Nipple down BOPE. 161,728 CUM:$ 1,342,255 ETD:$ 0 EFC:$ 2,602,255 09/02/96 (D 21) TD: 7785' ( 0) SUPV: RLM DAILY:$ MW: 8.4 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Nipple up BOPE. Test flanges to 300/3000 psi. Run 3.5" completion to 6732' Test casing to 3500 psi for 30 min. Freeze protect annulus. Rig released @ 2400 hrs. 9/2/96. 163,032 CUM:$ 1,505,287 ETD:$ 0 EFC:$ 2,765,287 End of WellSummary for Well:AK8605 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT A KI(3A-17(W4-6)) WFI I. JOB SCOPE JOB NUMBER 3A-17 PERFORATE, PERF SUPPORT 091196153 8.1 UN1T NUMBER DATE DAILY WORK 10/29/96 INITIAL A SAND PERFS OPERATION COMPLETE I SUCCESSFUL NO I YES -- Initial Tbg Press [ Final Tbg Press I Initial Inner Ann 0 PSII 800 PSII 600 PSI DAILY SUMMARY DAY 4 ,, KEY PERSON SUPERVISOR SWS-SCHWARTZ JORDAN Final Inner Ann I lmtlal L)r ;er Ann I P~nal Uuter Ann 600 PSII 500 PSI[ 500 PSI I SLT-J WELL LOG AND INITIAL A SAND PERF COMPLETE @ 7474'-7504' INTERVAL. ] TIME LOG ENTRY 0 8: 3 0 MIRU SWS E-LINE. PT BOP AND LUB 2000 PSI OK. 09:30 RIH W/CCL/GR & 2 1/8" OD SLT-J. 10:3 0 TIE IN ARC-5 LOG DATED 28 AUG 96 +5' CORRECTION. 10:35 TAG TI) @ 7706'; LOG MAIN PASS FROM 7706'-7150' 10:5 5 LOG REPEAT PASS FROM 7706'-7300' 11:05 POOH 12:00 AT SFC 12:30 SAFE-WY MTG FOR PERF RUN. SIGNS,,RADIOS, CELL PHONES, EAP. 12:45 lq' BOP, LUB 2500 PSI OK. RIH W/CCL-GR +IifX 2.5" HC GUNS/BIG HOLE/4SPF/180 DEG PItASING ORIENTED 2SPF 102 DEG CCW AND 2SPF 78 DEG CW FROM HIGH SIDE OF HOLE. 15:00 LOG TIE -IN PASS W/CCL-GR 7700'-7150' 15:15 LOG IN SHOOTING POSITION. CCL AT 7489'. TOP SHOT AT 7494' (10' GUN). TBG PRESS 0.PRESS TBG TO 1250 PSI. TBG PRESS DROP TO 1000 PSI AFTER SHOT. PULL 400~ OVER TO MOVE AFTER SHOT. 16:00 AT SURFACE. ALL SHOTS FIRED. WHP 350 PSI. 17:00 RIH W/CCL + 20' X 2.5" HC GUNS/BIG HOLE/4SPF/180 DEG PHASING ORIENTED 2SPF 102 DEG CCW AND 2SPF 78 DEG CW FROM HIGH SIDE OF HOLE. 3.5' CCL-TOP SHOT 17:35 LOG IN SHOOTING POSITION. WHP 1100 PSI. CCL AT 7470.5'/TOP SHOT AT 7474'.PERF 7474'-7494'. POOH. 18:30 AT SURFACE. ALI, SHOTS FIRED. RDMO SWS E-LINE. WHP 800 PS1. 12/6/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10616 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS C~ {~_ ~,~'~ Tape !3A-17 "~-~ 96244 ARC 5/ADN 4 MWD 960831 I ' 3A-17 96244 ARC5 960831 I 1 3A-17 96244 ADN 960831 1 1 , S I G N E D' ~___~__~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 11/6/96 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10543 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 2 X- 13 -~ c~ ... I-/~J PRODUCTION PROFILE 961 008 '1 1 3A-17 ~'(~- ~ "~ ~, CBL 961029 I 1 3A-18 c~ (..o-' I~'B CBL 961031 I 1 3J-19 ~ - 1 5r ~ CBL 961101 I 1 1 E- 19 ~ % - O t'"/ INJECTION PROFILE 9 61 01 9 I I SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: : h2CEIVED t. OV 0 8 ]996 Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnsto,~ Chairman DATE: September 1, 1996 THRU: FROM: Blair Wondzell, P. !. Supervisor FILE NO: Doug Amos, ',~% ~ SUBJECT: Petroleum Inspector 4cxhh2dd.doc Confidential: Yes _, NoX, Attachment Only . Casing Leak-Off Test Kuparuk Rv. Field KRU 3A-17 Well PTD # 96-0132 Wednesday, August 28, 1996: I traveled to Arco's KRU 3A-17 well to witness the Casing Shoe Test and Formation Leak-Off test on Parker Rig 245. The 7.625", 29~ per/fi, L-80 casing, shoe @ 3821' was tested to 2000 psi for 30 minutes. The final pressure after 30 minutes was 1975 psi. After drilling 10' of new formation the first of two formation leak-off tests were performed. The first leak-off test proved to be inconclusive therefore 20 additional feet of formation was drilled, the second leak-off test was acceptable providing an EMW of 13.48 PPG. The leak-off test data was submitted by Petroleum Inspector Lou Grimaldi's report 4COJH2DD. DOC& XLS. SUMMARY: I witnessed the successful casing shoe pressure test and formation leak-off test at Arco's KRU 3A-17 well. The test data is the subject of Petroleum Inspector Lou Grimaldi's report 4COJH2DD. DOC& XLS. Attachment: NONE 29. i996 £'4iPM A~_C~0 ALASKA !NC ~No. !492 ?, 1/7 ARCO Alaska, Inc. TRANSMISSION___ mber of Pages (Cover +): --~ (~ · ~! i! E II I! I E1 II ! II I! I ~11 III III1! I II II · II I! I I II II I II II I I &l II I IIII I · II II · I~ I! I I Il II I m II ii 14 · I ! II il il II I I i · I1 ....... l t, ~11 ,[~ ........ 1~1 '.I' ~llll ]11 II II III ~IE II Itl I!] ]11 II II lll ~ l~ I! !1 II] Ii II III · ii I! II II II Ii i II I !1 I ........ ,11 ,, Ill II II I& I ill I! Il Phone: Location: Kuparuk Drill Site Development P. O. BOX 100360 ANCHORAGE, AK 99510-0360 FAX # 907 265-622.4 ATO-1209 To: ~). Location: CopiesTo: ~, ~~1 Subject: FAX #: Phone #: 1998 2'42PM AP~0 ALASKA INC ARCO Alaska, Inc. Post O[fice I~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 121S August 29, 1996 I'~o. 1492 ?. 2/7 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subiect:. Annular Pumping Approval for ICRU Well 3A-17 Dear Mr. Johnston: Kuparuk River Unit Well 3A-17 was permitted to drill on July 30, 1996. The permit applical:[on included a request to approve this well for armular pumping operations for the period of one year. The application included information specified in the proposed regulations 20 AAC 25.080, but approval was contingent on the subsequent submittal of a Form 10-403 describing the well's surface casing cement job. Information included in the permit to drill application is not repeated here since it has already been submitted to the AOC~C. We believe that the 3A-17 surface cement job will provide an adequate seal for annular pumping operations and that the well has been cased and cemented according to regulation. ARCO Alaska, Inc., requests approval to commence annular pumping operations on this well as needed for waste disposal as described in the Permit to Drill application. , If you have any questions or input on the request for approval, please contact.the Drilling Engineer, Denise Petrash at 263-4183, or myself at 265-6206. Mike Zanghi Drill Site Development Supervisor .. AR3B-6003-93 2. a.2-2603 ,,~s, 29. 1996 2'42PM AR¢~_O. ALASKA No. 1492 STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type gl Request: Abandon_ Suspend _ Alter casing _ Repair well _ Change approved program _ Operation Shutdown Re-enter suspended well Plugging _ Time extension_ Stimulate _ Pull tubing_ Variance_ Perforate _ Other 2. Name of Operator ARCO Alaska. Jric, 3. Address !P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 663' FSL, 785' FEL, Sec. 7, T12N, RgE, UM At top of produclive interval 5. Type of Welh Development _X_ Exploratory _ Strafigraphic _ Service 967' FNL, 2719' FEL, Sec. 17, T12N, RgE, UM (planned) At effective depth At total depth 1114' FNL~ 24.1..8'~ FEL, Sec. 17, T12N, RgE,_,U.M (planned) 12. Present well condition summary Total Depth: 6. Datum elevation (DF or KB) Rio RKB 41' P_ad level 55' lest 7. Unit or Property name Kuparuk River Unit .. w.., 9. Pe~it number So-029-22691 ~. ~d~oo~ ~uparuk River Field Kuparuk River Oil Pool measured true vertical 3833' feet Plugs None 3316' feet (Note: preparing to drill out at 00:01 8/29/96) Elfective depth: measured 3733' feet Junk None true vertical 3239' feet Casing Structural Conductor Surface Inl~ermediate Production Liner Perforation Length Size 80' 16" 3780' 7-5/8" measured None true vertical Cemented Measured depth True vertical depth 250 Sx AS I 1 21 ' 1020 sx AS III & 3821' 340 sx Class G 121' 3307' ORIGINAL Tubing (size, grade, and measured depff~ None Packers and 855V (type and measured deplh) None 13, Attachments "=Description summary of proposal ~ Detailed operation program _ BOP sketch 14. Estimated date for commencing operation I15. Status of well classificalJon as: 9/1/96 I oil _X_ Gas _ 16. I! proposal-was verbally.appjoved I ' Name of approver ~ Date approved J Service 7.,.,,,t hereb~ certify that the foregoing is true'and coFrect'to the best of my knowledge. ' ;i'ne'~l~l~ ~~~ ~/~ '~ ("'""FORTitI"e .COMMISSION Drill Site Bev, SupV,usE ONLY Suspended Conditions of approval: Notify Oommisslon SO represenlative may witness ,Approval Plug integri{y_ BOP Test_ Location clearance ~ I ~/"~,~'_. Mechanical Integrity Test_ ,Subsequent torr~ require .10-_.~,,~0~,~-, Approve,d.._by' the order o~ the Commission Original Signed By commission_e_r__D_at,e ¢-~ -'cfm 10-403 Rev 06/15/88 Tuckerman Babcock SUBMIT IN TRIPLICATE Approved Copy Returned .~,29. !996 2:42PM ARCO ALASKA iNC - No, 1492 P. 4/7 KRU 3A-17 Annular Pumping Permit Application Additional Information Please see the attached "Cementing Details" form for Well 3A-17 for basic details on the cementirtg operation. Additional information is offered below irt support of ARCO Alaska Inc.'s opinion that the surface casing cement job will provide adequate sealing capability for annular pumping operations, and that the well has been cased arid cemented according to regulation (AAC 25.030). Surface Hole TD: 3833' MD / 3316' TVD Surface Hole Conditions: Tight spots were seen from the top of the West Sak to the base permafrost during the wiper trip at TD, but these were cleared up prior to pulling out of the hole. Casing was run to bottom without problems, with precautionary circulation occurring at 1827'. No fill was seen on bottom. Full returns were seen at all times. Casing Placement: The casing was stuck high off of the hanger in an attempt to reciprocate throughout the job. The pipe was completely free prior to this point. The surface casing shoe was placed at 3821' MD, 12' off bottom. 10-20' off bottom is the planned standard with fluted casing hanger assemblies. Cementing Details: Full returns were seen while circulating on bottom prior to cementing (11.5 bpm) and during the cementing operation itself (7.2 bpm). 98.6 bbls of 12.0 ppg cement were seen at surface. Excess on the lead cement was 230% (2.3 times the calculated gauge hole volume) and 30% on the tail cement. These excess factors were based on historical data and were very conservatively calculated with the intent of bringing cement to surface during the primary job. Based on the data, there should be an adequate seal for safe annular pumping operations. Diagnostic Logs: None. 29, 1996 2'42PM ARCO ALASKA INC = Ilo, 1492 P, 5/7 ARCO Alaska, Inc, Well#: Casing Size 7 5/8" Centralizers Cementin~l Details 3A-17 Field: KUPARUK Date: 08/27/96 Hole Diameter Hole Angle Shoe Depth Float Depth % washout 9 7/8" 40° 3821' 3r733' State type usedr intervals covered and spacin.cj 20 Gemco centralizers. 2 Gemeco Stop Collars. Mud Weight YP(prior cond) YP(after cond) J PV(prior cond) PV(after cond) 9.7/9.2 26 lbs/100 ft2 23 lbs/100 ft2l 20 cP 19 cP Total Volume Circulated Spacer Lead Cement Tall Cement Displacement Gels before 8/14 Type Water Gels after 6/12 879 BBLS @ 11,5 Volume 40 BPM, 70O..P..S../ Weight 8.3 PPG Type IMix wtr temp No. of sacks Weight Yield AS 3 I 55 1020 12.1 1.94 Additives .25 #/sk D29 TypeG IMix water tempi N°' °f sacks155 340 Weight 115.8 Yield 1.15 Additives G, 0..2.5_#/sk D29, 0.2% D46 Rate(before tail at shoe) 5.8 Reciprocation length 15' Calculated top of cement SURFACE Theoretical Displacement 171.7 t' C IP 8/2.7/96 2211 hrs. 0.3% D65~..1% S001 Rate(tail around shoe) 5.8 Reciprocation speed 10 fpm Actual Displacement 173,6 Bumped plug IFl°ats held NOI YES Str. Wt. Up 165 Str. Wt. Dn 140 Str, Wt, Mud 140 Remarks; Include whether full returns were obtained, reciprocation throughout.operation and any other pertinent Information. -lad full returns while circulating prior to cement Had full returns while pumping cement and disp__la_c!ng same. Final displacement pressure 1500 )si at 7,2 bpm. Had 12.0 ppg. cement to surface after pump.in.g 75 bbls of displacement. Had 98,6 bbls, 12 ppg cement returns to surface. ~Picked up off hang.er after dropping top plug an_al_stuck casinq high. Cement Company ]Rig Contractor I Signature Dowell IParker 1 R, L, Morrison Jr. 29. 1996 2'43P1V[ ARCO ALASKA I~,IC No. 1492 P. CASING A~D LEAK-OFF FRACT.U. RE TESTS Well Name: KRU 3A-17 Supervisor: R.L. Morrison Jr, Date: 8/29/96 Casing Size and Description: Casing Setting Depth: Mud Weight: 8.5 7 5/8~, 29.7#, L-80, BTC MOD 3821' TMD 3309' TVD ppg EMW -- Le..ak-off Pressure (PLO) + MW 0.052 x TVD LOT #1 =925 psi/(0.052 x 3309 tt) + 8.5 ppg -- 13.88 pl~, Hole Depth (md)= 3843 Fluid Pumped = 2.21 bbls. Fluid bled back = 2.0 bbls 2000 1900 lS00 1700 1600 1~oo 1400 13oo 12oo 1100 1000 800 70O 600 500 400 300 20o lOO o ,, i /', --e-- LEAK-OFF TEST ,~____ ~ I ~ CASING TEST___ STROKES ~ua, 29. 1996 2'437M ,A~O ALASKA ~¢o, 1492 P. 7W7 CASING AND LEAK-OFF_FRACTURE TESTS. Well Name: KRU 3A-17 Supe~/isor; R.L. Morrison Jr. Date: 81fi9/96 Casing Size and Description: Casing Setting Depth' Mud Weight: 8.50 7 5/8, 29:.7#, L-80r BTC ... 3821' TMD 3309' TVD ppg EMW = _Lea,k,-off Pressure (PLO) + MW 0,052 x TVD LOT #2 -- 865 psi / (0.052 x 3309 tt) + 8.5 ppg = 13.53 ppg Fluid bled back= 2.0 Fluid pumped= 2.3 Hole Depth (md)= 3863 2000 1900 1800 1700 1800 1500 1400 1300 1200 1100 1000 900 800 700 600 400 200 100 0 TONY KNOWLES, GOVERNOR July 30, 1996 ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mike Zanghi, Drlg Engr Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 3A- 17 ARCO Alaska, Inc. 96-132 663'FSL, 785'FEL, Sec 07, T12N, R09E, UM 1114'FNL, 2418'FEL, Sec 17, T12N, R09E, UM Dear Mr Zan~fi: Enclosed is the approved application for permit to drill the above referenced ~vell. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) vdth pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that 5vere run. The documentation submitted should include a CQL or a valid LOT to assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be ~ven so that a representative of the Commission may Mtness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope BY ORDER OF THE COMMISSION dlf/encl c: Dept offish & Game, Habitat Section- w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALkSKA AL~,,.,KA OIL AND GAS CONSERVATION COMMIS~,,ON PERMIT TO DRILL 20 AAC 25.005 la. Type ot Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry i-'1 Deepen ~11 Service BI Development Gas BI Single Zone X Multiple Zone r-! 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Rig RKB 41', Pad 41' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Ancho,rac, le, AK 99510-0360 ADL 25632, ALK 2565 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 663' FSL, 785' FEL, Sec. 7, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 967' FNL, 2719' FEL, Sec. 17, T12N, R9E, UM 3A-17 #U-630610 At total depth 9. Approximate spud date Amount 1114' FNL~ 2418' FEL Sec. 17, T12N, R9E, UM 8/8/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3A-08 7761' MD 967 @ tare, let feet 16.4' @ 160' feet 2448 6341' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 812' feet Maximum hole angle 40° Maximums~rface 1955 psig At total depth (TVD) 3300 pslg 18. Casing program Settinc, I Depth. size Specifications Top Bottom Quantity of cement Hole Castrol Weight Grade Couplin~ Lenc~th ME) TVD ME) TVD tinclude sta~le data) 24' 16' 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875' 7.625' 29.7# L-80 LTC 3752' 41' 41' 3793' 3302' 1030 Sx Arcticset III & HF-ERW 300 Sx Class G 6.75' 5.5' 15.5# L-80 LTCMOD 7161' 41' 41' 7202' 5913' HF-ERW 190 Sx Class G , 6.75' 3.5' 9.3# L-80 EUESrdM 559' 7202' 5913' 7761'. 6341' Top 500' above Kuparuk 19. To be completed lor Redrill, Re-entry, and Deepen Operations. Present welt 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 Surf.ce ," r:: ', Intermediate ~, !ii: ~... ~,. i ~'~ '~' v Production Liner Perforation depth: measured true vertical A. Iq.Sb.:: r',',~ ,% ,'? ..... (" ".?, 20. Attachments Filing fee X Property plat E] BOPSketch X Diverter Sketch X /'.,ii?l;.31~.riJ§ng program X Drilling fluid program X Time vs depth plol [] Relraction analysis [] Seabed report ri 20 AAO 25.0,50 requirements X Sigr~ly~~/~-~ ~~.~~ ~~ ~. Title Drill Site Develop. Supv. Date · ' !.l ~ ' Commission Use Only Perm~Number . ~ APl Ih4h~ber _ __ ~ ,....~ ~, J Approval date ~ ~ ¢'-) ~/ ~ See cover letter for ~-~'~::::; - ~'~ ! 50- ~'~__..~' -- ~ ~ ~ ~/ I //'~ "-~"~'" 7 ~ I other requirements Conditions of approval Samples required !--] Yes ~ No Mud log required F'] Yes .,~ No Hydrogen sulfide measures ,j~ Yes r'l No Directional survey required ~ Yes r-I No nequired working pressure for BOPE r-I 2M ~] 3M BI 5M I-'1 10M i-i 15M Other:. 0rigina.! <::,:~',~.:0 oy ,, order of Approved by David W. Johnston Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate · . 10. 11. 12. 13. 14. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3A-17 Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (3,793')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test, t~. Drill 6-3/4" hole to total depth (7,761') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 3-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test 5-1/2" x 3-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE. NU tubinghead & master valve and upper tree assembly. Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 3A-17 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,955 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3A-17 is 3A-08. As designed, the minimum distance between the two wells would be 16.4' @ 160'. Drillin~ Area Risks' Risks in the 3A-17 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 3A-17 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3A-17 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3A-17 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3A surface casing shoes will be set +200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a m~m~aximum o_Lt~.0~;;~pg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Shoe Pressure = 3560 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft)Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC-M 4990 4 2 4 2 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). F:... ~'''' ~/; ~'' ARCO ALASKA, Inc. Pad 3A Yell : 17 slot #17 Kuparuk River Unit North Slope, Alaska ~-D M I N I M U M D I STANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 17 Version #4 Our ref : prop1615 License : Date printed : 19-Jul-96 Date created : 30-Apr-96 Last revised : 19-Jul-96 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on nTO 24 4.812,w149 55 52.391 Slot location is nTO 24 11.332,w149 56 15.392 Slot Grid coordinates are N 5997044.205, E 507664.982 Slot local coordinates are 663.00 N 785.00 Y Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 DECREASING CLEARANCES of less than 1000 feet are indicated Object wellpath Closest approach with 3-D Last revised Distance Pr.~ts <0-8475'>,,4,Pad 3A 30-Apr-96 115.6 PGMS <0-8390'>,,3,Pad 3A 30-Apr-96 140.1 Pr, MS <O-7630'>,,13,Pad 3A 2-Jan-92 158.4 PC, MS <O-8024'>,,12,Pad 3A 2-Jan-92 129.4 P¢..~IS <O-7350'>,,11,Pad 3A 2-Jan-92 107.4 PGMS <O-7000'>,,lO,Pad 3A 2-Jan-92 80.6 HMS <O-6400'>,,YS-23,Pad 3A 2-Jan-92 58.9 Pr..~IS <O-7120'>,,8,Pad 3A 2-Jan-92 16.4 PMSS <O-7275'>,,7,Pad 3A 2-Jan-92 31.1 PGM$ <O-?680'>,,6,Pad 3A 2-Jan-92 53.3 PGMS <O-8660'>,,5,Pad 3A 2-Jan-92 90.5 PGMS <O-8690'>,,2,Pad 3A 2-Jan-92 165.0 PGM$ <O-9600'>,,1,Pad 3A 2-Jan-92 191.3 PGMS <O-9155'>,,16,Pad 3A 2-Jan-92 231.9 PGMS <O-8160'>,,15,Pad 3A 2-Jan-92 207.1 Pr~s <O-7855'>,,14,Pad 3A 2-Jan-92 ~ 184.1 18 Version ~6,,18,Pad 3A 19-Jul-96 249.4 by an asterisk, e.g. 487.4* Minimum Distance method M.D. Diverging from M.D. 220.0 220.0 220.0 220.0 811.7 811.7 560.0 560.0 811.7 811.7 836.7 836.7 20.0 20.0 160.0 986.7 1136.7 1136.7 1211.7 1211.7 420.0 420.0 160.0 160.0 140.0 140.0 560.0 56O.O 620.0 620.0 20.0 20.0 28O.O 280.0 350 35O 7OO 1050 1400 1750 2100 2450 2800 3150 > 35o0 F.~ 3850 I 44200 4550 4900 5250 5800 5950- 6300 665O 350 ISURFACE LOCATION: 663' FSL, 785' FEL SEC. 7, T12N, R9E ARCO ALASKA, Inc. Structure : Pad 3A Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) ->' 400 0 400 800 1200 1600 2000 2400 2800 3200 3800 I I I I I I I I I I I I I I I I i I I I I RKB ELEVATION: 82' KOP TVD=812 TMD=812 DEP=O 3.00 6.00 9.00 12.00 BUILD 3 OEO / 100' 15.00 18.00 21.00 24.00 B/ PERMAFROST TV0=1582 TMD:1605 DEP=162 27.00 30.00 33.00 36.00 T/ UGNU SNDS TVD=1992 TMD=2084 DEP=408 39.00 EOC TVD=2039 TMD=2145 DEP=447 · TARGET LOCATION: 967' FNL, 2719' FEL SEC. 17, T12N, R9E TARGET TVD=5942 TMD=7240 DEP=3722 SOUTH 1630 EAST 3346 T/ W SAK SNDS TVD=2682 TMD=2984 DEP=986 AVERAGE ANGLE 40 DEG B/ W SAK SNDS TVD=3102 TM0=3532 DEP=1338 7 5/8" CASING PT TVD=3302 TMD=3793 DEP=1506 8/ HRZ -r'VD=,~807 TMD=7063 DEP=3608 TARGET - T/ D UNIT TVD=594~ TMD=7~40 DEP=37~2 T/ A3 INTERVAL 'rvo=60B5 TMD=7426 OEP=3842 B/ KUP SNDS TVD=6188 TMD=7561 DEP=3928 TD - 5 1/2" CSG PT TVD=6341 TMD=7761 DEP=4057 i i i i ]i J i i I i I II i II ~ IJ J 350 700 1050 1400 1750 2100 24450 2800 3150 5500 Vertical Section (feet) -> Azimufh 115.98 with rofor~nco 0.00 N, 0.00 E from slof #17 TO LOCATION: 1114' FNL, 24-18' FEL SEC. 17, T12N, R9E 4000 I 4O0 4O0 800 1200 6OO 2OO0 S 64.02 DEG E i i i i 5850 4200 Created by jones For: D PETRASH] Dote plotted : 22-Jul-96 Plot Reference Is 17 Version 1//4, Coordinates ore in feet reference slot. ~17. True VerUcol Depths ~ RKB (Porker ARCO ALASKA, Inc. Structure : Pad SA Well: 17 Field : Kuparuk River Unlt Location : North Slope, Alaska 8O 4O 120 Q) ¢' 160 0 U') 200 I 'v' 24-0 280 320 560 4O0 East (feet) -> 0 40 80 120 160 200 24-0 280 320 360 400 440 480 520 560 600 640 680 720 760 800 40 I I . I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I' I I I [ I I ! I [80 800 2800 2200 I00 800 1000 3800 260O 2800 1200 4O 80 i i 4'0 0 120 0 160 200 24O 1400 1600 3200 % 4-10 i 8 / i i i [ i i i i i i i i i i i i i i t i i i i i i i i i i i i i 0 120 160 200 240 280 320 360 400 440 480 520 560 600 640 680 720 760 800 East (feet) -> 360 320 1200 1400 3000 280 20" ,.~PARUK RIVER UNIT DIVERTER SCHEMATIC I 5 4 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20"-2000 PSI DRILLING SPOOLWITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20' - 2000 PSI ANNULAR PREVENTER EDF 3/10/92 J ,6 , 13 5/8" 5000 PSI STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 5 BOP STACK TEST 1. 16" - 2000 PSI STARTING HEAD 2_ 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13~o/8" - 5000 PSI PIPE RAMS 5. 13~/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 1:~5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PiPE RAMS AND CLOSE BO~-~OM PIPE RAMS. TEST BoTrOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE THE BOP STACK TEST WILL BE CONDUCTED AS DESCRIBED ABOVE, BUT WILL BE TESTED TO 5000 PSi HIGH. ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL ALSO BE TESTED TO 250 PSI LOW. · WELL PERMIT CHECKLIST COMPANY..Z WELL NAME PROGRAM: O D n. FIELD & P~L ~ ~ ~ ~ IN~ C~SS ~p/~ ~--~ ~/ GEOL AR~ ~ ~ UNIT~ //~ ON/OFF SHORE ADMINISTRATION o 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 1. Permit fee attached ...................... .Y 1 2. Lease number appropriate .................. I · Y Unique well name and number ................. t Y Well located in a defined 13oo1 .................. Y Well located proper distance from drlg unit boundary ..... Y Well located proper distance from other wells ......... Y Sufficient acreage available in drilling unit. .......... Y if deviated, is wellbore plat included .............. Y Operator only affected party .................. Y Operator has appropriate bond in force ............ Permit can be issued without conservation order ...... Permit can be issued without adminisl]'ative approval .... Can permit be approved before 15-day wait. ........ ........... ENGINEERING REMARKS N N N ., GEOLOGY 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided .................. ./~'~ N Surface casing protects ail known USDWs ......... ~ N CMT vol adequate to circulate on conductor & surf csg . . . N CMT vol adequate to tie-in long siting to surf csg ....... CMT will cover all known productive horizons .......... Y'~' Casing designs adequate for C, T, B & permafrost. ..... ~ N Adequate tankage or reserve pit ................ ~ N If a re-drill, has a 10-403 for abndnmnt been approved .... Adequate wellbore separation proposed ............ ~' ;) N If diverter required, is it adequate ................ (~) N Drilling fluid program schematic & equip list adequate .... ~ ~ N BOPEs adequate ........................ ~. ) N BOPE press rating adequate; test to '~ ~ psig. ~ ~) N Choke manifold complies w/APl RP-53 (May 84) ....... N Work will occur without operation shutdown .......... / N is presence of H2S gas probable ............... ) N Permit can be issued w/o hydrogen sulfide measures ..... Y Data presented on potential overpressure zones ....... y Seismic analysis of shallow gas zones ............. /Y/ N Seabed condition survey (if off-shore) ........... .//Y N Contact name/phone for weeld¥ procjres:s, repo~ ...../.. Y N lexp~oratory on(y] 30. 31. 32. 33. 34. ENGINEERING: COMMISSION: BEW~'/'/,ES~ DWJ ~ JDH ~ JDN TAB ~ Comments/Insb'uctions: HOW/II~ - A,'~'OR~ist rev 4/96 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 simp!ify finding information, informati;3n 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. 00'0 00'0 00~0 00+0 NOI&~I:3NI : (dll)lNIOd NI Eli ,M-/~)d20 00'0 (S-/N)i~ :NOIiV3L~I GV3H ::3M 00'0 r' ~ O0-I,.,v~- .,~0-0~ ,'ON tdV S09B)JV :2Er I 'ON 2.~d PAGE NO. MEASURED iNI'~VAL VERTICAL DEPTH D~'TH ft ft ft 121.00 0,0 i21,00 454,00 33.3,0 453.98 649,31 195.3 649,28 742,27 93,0 742,23 821,00 78,7 820,92 914.00 I005.00 1097.00 !200,60 t294.72 1~5.76 1477.42 1572.25 !664.37 1758.!6 !849.47 1941.50 20.36,62 2130.64 2407.66 26~.24 2966,30 3244,34 3520,00 3- 7_.2, ly 3974.14 4256,24 4531,50 4808,70 5085.64 5358.70 5633.58 5?(5.44 6095.13 6917.75 7297,80 70o~.Ov 93.0 913,61 91.0 1003,56 92.0 I093.41 i03.6 115~,42 94.1 1283.45 91.0 1370,14 91,7 1456.85 94,8 i545.58 92~I i630,79 93,8 17!5,8t 91.3 1795,82 92.0 1873.04 95.1 1949.96 94.0 20~,34 277.0 2232,06 282,6 2445,27 7~ 2. o,1 2657,84 278,0 2869,30 ~5.7 .3O77,26 232,2 3255,81 221,9 3428,14 282,1 3645,03 275,3 .3854,74 277.2 4065.14 276,9 4274,4i 15,4 4480,11 274,9 4682,96 274,9 4884,23 18o,~ a023.o4 274,3 523~.10 274.6 5445,30 273,8 5658,51 380.0 ~ '^ 367,2 ~242,37 ************* ANADRILL ************** SURVEY CALCU~TIONS ************* CIRCULAR ~ M~HOD******** TARGET STATION AZIMUTH LAT!~JDE S~TI~4 INCLN, W-S ft deg deg ft 0,00 0.00 0.00 0.00 -I,18 1.00 230.00 -t.87 -2.10 0.51 22i,04 -3,62 -1.31 1,12 121.63 -4,40 1.16 2.50 123.00 -5,74 3A-i7 DEPARTURE DISPLACEMENT at E/-W ft ft 0.00 OJX) -2,23 2,91 -4.10 5.47 -.~,.~0 5,69 -1,5! 5 '~ AZIMUTH deg 0,00 230,00 228,59 219.28 194,73 DLS deg/ lOOft 0,00 0.30 0,26 1.40 1,76 8,34 6.50 127.00 -10,01 4,40 10,94 156.28 4,31 21.73 10.75 I27,00 -18.22 15.30 23.79 139,99 4,67 41,12 i4.00 126.00 -~,93 31,16 43.20 133.85 3.54 67,50 16.27 1~,73 -46,77 52,2? 70,16 131.81 2,49 94.58 17.73 117.45 -61,98 75.01 97,3i 129.57 4.40 12~,40 17.86 ti4,54 -74.17 i52.11 t9,99 i16.98 -87,12 o~,_~ 21.32 118,73 -102.75 220,50 23,35 118,67 -119,57 260.05 26,57 1!7.95 -138.32 303.97 30.?7 116.18 -i58.27 354.01 34.91 ii6,1i -~80.~ 409.96 37.17 117.24 -~5,46 468,69 40,20 117,89 -232.65 650,75 42.01 117.04 -316.63 836.14 40,01 I17,21 -40i,17 1012.26 39.28 116.14 -480,26 !192.77 41,69 115.97 -557+53 t373.70 40.36 115.52 -638,13 1522.09 39.I2 114,28 -700,64 1661,8i 39°02 112.28 -755.93 i841.99 40,48 I14,65 -827,79 2020.28 40.27 116.63 -904,74 25~0,68 4{),98 118,39 -988,31 2381.92 40.':/2 111.43 -!064.67 100,01 124.51 I26,56 0.99 i26,76 153,81 124,50 2,47 156.32 187.07 123.32 1.55 187,03 221,98 122.59 2.21 221,88 261.46 121,94 3,45 261.02 305.25 121,23 4,91 305,93 355,12 120.52 4,28 · 355,93 410,97 120,00 2,47 408,01 ~9,68 119°69 3,26 569,61 651,69 119,07 0.69 734,64 837,04 118.64 892.02 10!3,07 118,30 i054,!? 1193.48 117.96 12!7,16 1374,29 117.67 1351.~ 1522,56 117,40 1480,25 1662,10 117,05 1645,67 1842,14 116,70 1806,41 2020,40 116,61 1966.46 2200.85 116.68 2130,86. 2382,03 116,55 2291,44 2561,39 116.54 2450,92 2746,43 116,82 2614.56 2?33.47 116,96 2723.89 3057.58 117.02 2882.32 3234.61 116.97 3042.90 3408,35 116,78 3201.24 3579,70 114.58 34i8,67 3816,35 116,39 3630.16 4045,25 116,18 2561,27 4!,90 121.50 -I144,55 2746.13 42,?? 119.95 -1237,30 2?33.04 42,86 1i8,13 -1330.16 ~57°08 40,51 118,43 -1388,97 ~o..10 39.93 114,55 -1467.97 34C8,02 38.86 Iit000 -1535,46 3~9 ~^ ~.,_~ ~,87 1i4,57 -1601,97 3~16,26 38.30 i12.30 -1696.25 4045,22 3?,00 113,19 -1784,93 0,71 0,36 0,87 0,50 0,63 0.57 0.75 0.47 0,49 1.65 4.34 0,55 0,45 1.26 0,94 0,91 0.82 0,40 0,24 PAGE NO, 3 ************* ANADRILL SURVEY CALCULATIONS *******~**** CIRCULAR~ METHOD******** MEASURED INTERVAL V~RTICAL TARGET D~PTH D~F~H S~TION ft ft ft ft PROJECTED '~ TD .4~ 7784,50 It9,0 ~,o~ STATION AZIMU~I LATITUDB INCLN, N/-S deg deg ft 4120,02 39,00 113,17 -1814.42 3A-1Z D~PAF.~UR~ DISPLACEMENT at AZIMLITH DLS ~/-W deg/ ft ft deg lOOft 3697,00 4120.04 116,13 0,02 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1996 11:31 PAGE: **** REEL HEADER **** SERVICE NAME .. EDIT DATE · 96/12/ 5 ORIGIN : FLIC REEL NAM~ '. 96244 CONTINUATION # : PREVIOUS REEL : COlV~4~f : ARCO ALASKA INC., KUPARUK 3A-17, API #50-029-22691-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/12/ 5 ORIGIN : FLIC TAPE NAME : 96244 CONTINUATION # : 1 PREVIOUS TAPE : COf~4ENT : ARCO ALASKA INC., KUPARUK 3A-17, API #50-029-22691-00 TAPE HEADER KUPARUK RIVER MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION BIT RUN1 96244 MILTON MORRISON SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2NDSTRING 3A-17 500292269100 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 5-DEC-96 BIT RUN 2 96244 MILTON MORRISON BIT RUN 3 7 12N 9E 82.00 82.00 41.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 3821.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1996 11:31 3RD STRING PRODUCTION STRING Well drilled 28-AUG through 31-AUG-96 with ARCS/ADN4. Ail data was collected in two bit runs. The ADN4 data was obtained during Field Test. The curves from the ADN4 are as follows: RHOB=ROBB(Bottom Quadrant Density) DRHO=DRHB(Bottom Quadrant DRHO), TNPH=TNPH, RPM=RPM. The log was depth shifted to the SWS CBT logged 29-0CT- 96. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION . O01CO1 DATE : 96/12/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMEiFT: 0.5000 FILE S~Y LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 7780.5 3721.0 BASELINE DEPTH .............. 88888 0 7693 0 7682 5 7672 0 7647 5 7642 5 7631.5 7610.0 7591.0 7573.0 7565.5 7562.5 7555.0 7538.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... ....... 88884.0 7689.0 7679.0 7668.0 7643.5 7639.0 7631.0 7609.5 7590.0 7572.0 7565.5 7564.0 7555.5 7539.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1996 11:31 PAGE: 7529 7517 7511 7502 7497 7487 7482 7460 7448 7446. 7427.0 7403.0 7396.5 7392.0 7375.0 7370.5 7362.5 7356.0 7345.0 7335.5 7328.5 7322.5 7320.0 7294.0 7287 0 7262 5 7250 5 7244 0 7235 0 7230 5 7219.5 7204.5 7194.0 7182.5 3825.0 M~ERGED DATA SOURCE LDWG TOOL CODE REMARKS: 7530.5 7518.0 7512.0 7503.0 7498.0 7486.5 7483.0 7461.5 7449.0 7447.0 7423.0 7395.5 7389.0 7384.0 7366.5 7362.0 7354.5 7348.0 7337.5 7329.0 7318.5 7312.5 7310.0 7283.5 7277.0 7253.0 7241.0 7236.0 7225.0 7219.0 721 O. 0 7192.5 7184.0 7172.5 3825.0 BIT RUN NO. MERGE TOP MERGE BASE 1 3721.0 7376.0 2 7266.0 7780.5 The depth adjustments shown above reflect the MWD GR to the CBT GR logged by SWS. Ail other MWD curves were carried with the GR. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1996 11:31 PAGE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD F/HR O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RPXXMWD OHMM O0 000 O0 0 1 1 1 4 68 0000000000 RPX MWD OH~ O0 000 O0 0 1 1 1 4 68 0000000000 RPS MWD Ott~ O0 000 O0 0 1 1 1 4 68 0000000000 RPM MWD OH~ff~ O0 000 O0 0 1 1 1 4 68 0000000000 RPD MWD OPL~I O0 000 O0 0 1 1 1 4 68 0000000000 RHOB MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CBT GAPI O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7780.000 ROP.MWD 123.750 FET.MWD -999.250 GR.f~fl9 RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 NPHI.MWD GRCH. CBT -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1996 11:31 PAGE: DEPT. 7000.000 ROP.MWD RPY. X.MWD 3.253 RPX.MWD RPD.MWD 3.315 RHOB.MWD GRCH. CBT -999.250 DEPT. 6000.000 ROP.MWD RPXi~.MWD 3.508 RPX.MWD RPD.MWD 3.401 RHOB.MWD GRCH. CBT -999.250 DEPT. 5000.000 ROP.MWD RPXX.MWD 2.871 RPX.MWD RPD.MWD 2.473 RHOB.MWD GRCH. CBT -999.250 DEPT. 4000. 000 ROP.MWD RPXX. MWD 5.073 RPX. MWD RPD.MWD 7. 426 RHOB.MWD GRCH. CBT -999. 250 DEPT. 3721.500 ROP.MWD RPXX.MWD -999.250 RPX.MWD RPD.MWD -999.250 RHOB.MWD GRCH. CBT -999.250 165. 000 FET.MWD 3.237 RPS.MWD 2.372 DRHO. MWD 165. 000 FET.MWD 3. 731 RPS.MWD 2. 337 DRHO. MWD 123.750 FET.MWD 2.795 RPS.MWD 2.326 DRHO.MWD 180. 000 FET.MWD 5.228 RPS.MWD 2.117 DRH O . MWD -999.250 FET.MWD -999.250 RPS.MWD -999.250 DRHO.MWD 0.628 GR.MWD 3.387 RPM.MWD 0.046 NPHI.MWD 0.364 GR.MWD 3.884 RPM. MWD 0.166 NPHI.MWD 0.372 GR.MWD 2.662 RPM. MWD 0.089 NPHI.MWD 0.131 GR.MWD 6.346 RPM. MWD 0.560 NPHI.~D -999.250 GR.MWD -999.250 RPM. MWD -999.250 NPHI.MWD 150. 753 3. 469 43.132 74.938 3.738 44.543 61.111 2.537 40. 304 95.756 7.594 40.778 -999.250 -999.250 53.729 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE ' 96/12/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW MWD LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1996 11:31 PAGE: Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 7376.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 3721.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR ADN4 NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~I) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 31 -AUG-96 4. OC 4.0 MEMORY 7784.0 3725.0 7784.0 80 38.9 39.1 TOOL NUMBER ARC-O14 ADN4 - ENPO 01 6. 750 3821.0 LSND 10.80 44.0 800 2. 540 72.0 2. 360 72.0 2. 700 72.0 SANDSTONE 2.65 1.0 20000 LIS Tape Verification Listing Schlumberger Alaska Computing Center $-DEC-1996 11:31 PAGE: REMARKS: ************ RUN 1 ************* DRILLED INTERVAL 3833' - 7376' RES TO BIT: 42.0'; GR TO BIT: 46.9' ************ RUN 2 ************* DRILLED INTERVAL 7376' - 7784' RES TO BIT: 42.0'; GR TO BIT: 46.9' TD WELL @ 11:30 31-AUG-96 DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT ll 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 FET LW1 HR O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 RPXX LW1 OH~ff4 O0 000 O0 0 2 1 1 4 68 0000000000 RPX LW1 OFi~M O0 000 O0 0 2 1 1 4 68 0000000000 RPS LW1 OH~M O0 000 O0 0 2 1 1 4 68 0000000000 RPM LW1 OH~4M O0 000 O0 0 2 1 1 4 68 0000000000 RPD LW1 OPff4M O0 000 O0 0 2 1 1 4 68 0000000000 DPHI LW1 PU O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1996 11:31 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TNPH LW1 PU O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LW1 G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LW1 G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 RPM LW1 RPM O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7376.000 ROP . LW1 90.000 FET. LW1 0.414 GR . LW1 RPXX. LW1 4.032 RPX. LW1 4.236 RPS.LW1 4.388 RPM.LW1 RPD.LW1 4.175 DPHI.LW1 -999.250 TNPH. LW1 -999.250 RHOB.LW1 DRHO. LW1 -999. 250 RPM. LW1 -999. 250 DEPT. 7000.000 ROP. LW1 180.000 FET. LW1 1.164 GR . LW1 RPXX. LW1 3.161 RPX. LW1 3.096 RPS.LW1 3.270 RPM. LW1 RPD.LW1 3.023 DPHI.LW1 15.265 TNPH. LW1 42.160 RHOB.LW1 DRHO. LW1 O. 052 RPM. LW1 63. 770 DEPT. 6000. 000 ROP. LW1 151.145 FET. LW1 O. 375 GR. LW1 RPXX. LW1 3.253 RPX.LW1 3.337 RPS.LW1 3.354 RPM. LW1 RPD.LW1 3 . 026 DPHI.LW1 21 . 026 TNPH. LW1 48. 417 RHOB. LW1 DRHO . LW1 0.1 O1 RPM. LW1 75.379 DEPT. 5000 . 000 ROP. LW1 116. 471 FET. LW1 0 . 381 GR. LW1 RPXX. LW1 2. 705 RPX. LW1 2. 721 RPS.LW1 2. 630 RPM. LW1 RPD.LW1 2. 467 DPHI.LW1 18. 759 TNPH. LW1 39. 016 RHOB.LW1 DRHO. LW1 0.118 RPM. LW1 85. 583 DEPT. 4000.000 ROP.LW1 180.000 FET. LW1 0.133 GR.LW1 RPX~. LW1 4. 327 RPX. LW1 4. 760 RPS. LW1 5. 880 RPM. LW1 RPD.LW1 6.340 DPHI.LW1 32. 442 TNPH. LW1 38. 775 RHOB.LW1 DRHO. LW1 O. 555 RPM. LW1 O. 000 DEPT. 3721 . 000 ROP. LW1 -999. 250 FET. LW1 -999. 250 GR. LW1 RPXX. LW1 -999.250 RPX. LW1 -999.250 RPS.LW1 -999.250 RPM. LW1 RPD. LW1 - 999.250 DPHI. LW1 -999. 250 TNPH. LW1 - 999.250 RHOB. LW1 DRHO. LW1 -999. 250 RPM. LW1 -999. 250 96. 067 4. 352 -999.250 153.781 3.320 2.398 86.665 3.225 2.303 56.995 2.515 2.340 92.960 6.786 2.115 - 999. 250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1996 11:31 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE · 96/12/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREM~a~T: 0. $ 000 FILE SUAff4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 7784.5 7256.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SO-RFACE SOFTWARE VERSION: DOWArHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME) TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR ADN4 NEUT./DENS. $ 31 -AUG-96 4.0C 4.0 MEMORY 7784.0 3725.0 7784.0 65 38.9 39.0 TOOL NUMBER ARC-O14 ADN4-ENPO01 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1996 11:31 PAGE: 10 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 6. 750 3821.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 11.10 MUD VISCOSITY (S) : 42.0 MUD PH: MUD CHLORIDES (PPM) '. 650 FLUID LOSS (C3): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 540 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 360 MUD CAKE AT (MT): 2. 700 NEUTRON TOOL MA TRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ************ RUN1 ************* DRILLED INTERVAL 3833' - 7376' RES TO BIT: 42.0'; GR TO BIT: 46.9' ************ RUN2 ************* DRILLED INTERVAL 7376' - 7784' RES TO BIT: 42.0'; GR TO BIT: 46.9' TD WELL @ 11:30 31-AUG-96 DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA 72.0 72.0 72.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1996 11:31 PAGE: 11 TYPE REPR CODE VALUE 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 ROP LW2 F/HR O0 000 O0 0 3 1 1 4 68 0000000000 FET LW2 HR O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 RPX~f LW2 OH~4~ O0 000 O0 0 3 1 1 4 68 0000000000 RPX LW2 OPff414 O0 000 O0 0 3 1 1 4 68 0000000000 RPS LW2 OHMM O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 OH~M O0 000 O0 0 3 1 1 4 68 0000000000 RPD LW2 OH2W~4 O0 000 O0 0 3 1 1 4 68 0000000000 DPHI LW2 PU O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LW2 PU O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHO LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 RPM O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 7784.500 ROP~LW2 123.750 FET.LW2 0.657 GR.LW2 RPXX.LW2 3.254 RPX. LW2 3.280 RPS.LW2 3.302 RPM. LW2 RPD.LW2 3.157 DPHI.LW2 -999.250 TNPH.LW2 -999.250 RHOB.LW2 DRHO.LW2 -999.250 RPM. LW2 -999.250 DEPT. 7256. 000 ROP. LW2 360. 000 FET. LW2 O. 000 GR. LW2 RPJOf. LW2 1000. 000 RPX. LW2 1000. 000 RPS. LW2 O. 227 RPM. LW2 RPD.LW2 1. 000 DPHI.LW2 -999.250 TNPH. LW2 -999.250 RHOB.LW2 DRHO. LW2 -999. 250 RPM. LW2 -999. 250 71.597 3.259 -999.250 57.784 0.500 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1996 11:31 PAGE: 12 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/12/ 5 ORIGIN : FLIC TAPE NAME : 96244 CONTINUATION # : 1 PREVIOUS TAPE : CO~4~IENT · ARCO ALASKA INC., KUPARUK 3A-17, API #50-029-22691-00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 96/12/ 5 ORIGIN . FLIC REEL NAME : 96244 CONTINUATION # : PREVIOUS REEL : COI4~IENT : ARCO ALASKA INC., KUPARUK 3A-17, API #50-029-22691-00