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184-126
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2D-05 KUPARUK RIV UNIT 2D-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 2D-05 50-029-21157-00-00 184-126-0 W SPT 5830 1841260 1500 2750 2750 2750 2750 300 410 410 410 4YRTST P Bob Noble 8/8/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2D-05 Inspection Date: Tubing OA Packer Depth 815 2010 1965 1965IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250810110007 BBL Pumped:1.1 BBL Returned:1 Monday, September 22, 2025 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor 1 FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, August 20, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2D-05 KUPARUK RIV UNIT 2D-05 Src: Inspector Reviewed By: P.I. Supry Comm Well Name KUPARUK RIV UNIT 2D-05 API Well Number 50-029-21157-00-00 Inspector Name: Matt Herrera Insp Num: mitMFH210818070638 Permit Number: 184-126-0 Inspection Date: 8/14/2021 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2D-05 Type Inj w - TVD 5830 Tubing 2690X680 iType 2 76 0 - 2700—� PTD 1841260 Test SPT Test psi' 1500 IA 610 2000 1915 1910 BBL Pumped. 13 "BBL Returned: 1.4 OA 200 350- 350 350 Interval 4YRTST Notes' MIT -IA Performed to 2000 PSI Per Operations Friday, August 20, 2021 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 10,2017 TO: Jim Regg 1<c' ( E(zl I( 7 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2D-05 FROM: Chuck Scheve KUPARUK RIV UNIT 2D-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv..]gR— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2D-05 API Well Number 50-029-21157-00-00 Inspector Name: Chuck Scheve Permit Number: 184-126-0 Inspection Date: 8/7/2017 Insp Num: mitCS170808080602 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2D-05 Type Inj W TVD 5830 Tubing 2600 2600 2600 " 2600 PTD 1841260 Type Test SPT Test psi 1500 IA 510 2000 - 1940 1930 " BBL Pumped: 1.3 BBL Returned: 1.3 OA 220 • 260 ' 260 " 260 Interval 4YRTST P/F P Notes: SCANNED LE; Thursday,August 10,2017 Page 1 of 1 RECEIVED STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM ION AUG 2 3 .)O12 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon I Repair r Rug Perforations F Fbrf orate r o4asha 0;,'c, °Other' -jr" ls. Commission P w ell Alter Casing r Rill Tubing r Stimulate - Frac r Waiver r Time Exter4 l c ge Change Approved Program f Operat. Shutdow n r Stimulate - Other f Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. - Development r Exploratory r 184 - 126 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service — 50- 029 - 21157 -00 ' 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25658 ' " 2D -05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7990 feet Plugs (measured) None true vertical 6364 feet Junk (measured) 4210 Effective Depth measured 7718 feet Packer (measured) 7397, 7624 true vertical 6114 feet (true vertucal) 5830, 6030 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 116 116 SURFACE 3798 9.625 3823 3159 PRODUCTION 7938 7 7971 6345 Perforation depth: Measured depth: 7534'- 7578', 7678'- 7688', 7700' -7742' �)t. ' , 'ff ? l� f',/ . 0 /iv True Vertical Depth: 5951'- 5990', 6079' 6088', 6099' - 6137' Tubing (size, grade, MD, and TVD) 3.5, J -55, 7643 MD, 6047 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL HYD SET RETRIEVABLE PACKER @ 7397 MD and 5830 TVD PACKER - BAKER FB -1 PERMANENT PACKER @ 7624 MD and 6030 TVD SSSV - BAKER FVL SSSV @ 1888 MD and 1764 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: ..„ Copies of Logs and Surveys run Exploratory r Development r Service rcsi Stratigraphic E 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXXX GSTOR r WINJ WAN" GINJ r SUSP f SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -209 Contact James Ohlinger 265 -1102 Printed Name James Ohlinger Title Senior CTD Engineer Signature �� Phone: 265 -1102 Date h/20//e VL ,1 Form 10+I Revised 111/ 011, 2 3 2012 0R1G1NAL 13 � . Submit Original Only *e1, KUP III 2D-05 ConocoPhi lips ' & Well Attributes Max Angle & MD TD Alaska Inc Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) � ; 500292115700 KUPARUK RIVER UNIT PROD 46.94 3,925.00 7,990.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV: LOCKED OUT Last WO: 46.60 9/20/1984 Well Cenfc: - 2D -O5, 7/242012 215:36 PM - Schematic - Aaual Annotation Depth (MB) End Date Annotation Last Mod ... End Date Last Tag. SLM 7,842.0 12/28/2011 Rev Reason: LATERALS ninam 7/24/2012 Casing Strings F Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 35.0 116.0 116.0 62.50 H WELDED HANGER, 33 c- H ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd ''.,}.. SURFACE 95/8 8.921 34.9 3,832.9 3,163.8 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 33.0 _ 7,971.2 6,346,6 26.00 J -55 BUTT I Tubing Strings Tubing De String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING I 3 112 I 2.992 32.7 7,643.3 I 6,048.0 9.30 I J - 55 EUE8RD CONDUCTOR, 35 -116 Completion Details Top Depth ( NO) To p In Nomi... SAFETY VLV, ( o ( Top (ftKB) (MB) ( ") Item Description Comment ID (in) 1.8ee l 32.7 32.7 -0.29 HANGER FMC GEN III TUBING HANGER 3.500 1,887.9 1,763.5 39.90 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 7/26/94) 2.810 GAS LIFT, 7,383.2 5,818.2 29.85 PBR BAKER PBR 3.000 2'091 7,396.9 5,830.1 29.78 PACKER BAKER FHL HYD SET RETRIEVABLE PACKER 2.937 7,539.5 5,955.4 27.57 BLAST RING BLAST RINGS (2) 2.992 7,621.9 6,029.1 26.81 LOCATOR BAKER LOCATOR SUB w/ 5' SEALS 3.000 7,623.7 6,030.7 26.78 PACKER BAKER FB -1 PERMANENT PACKER 4.000 SURFACE, ,1 35 7,626.2 6,032.9 26.73 MILLOUT MILL OUT EXTENSION 2.992 FISH, 4,210 - - - - -(/ 7,639.2 6,044.4 26.51 NIPPLE CAMCO D NIPPLE NO GO 2.750 4 7,642.7 6,047.5 26.45 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 7626' during SWS (PROF on 2.992 GAS IFT, 08/23/08 4 -- Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, Top Depth 5,739 (ND) Top Inc! Top (ftKB) MB) (°) Description Comment Run Date ID (in) GAS LIFT, 4,210 3,425.6 45.07 FISH STAINLESS STEEL BAND FROM HOLEFINDER APPROX 11/30/2008 0.000 6,860 3/4 ":x9 "x 1/16" 0A5 LIFT, - 7,616 6,023.9 26.91 TBG Punches TUBING PUNCHES shot w/2" HSD GUN HJ CHARGES 1/28/2007 2.992 7,337 1/28/2007 �„ 7,639 6,044.2 26.52 WHIPSTOCK BAKER MONOBORE WHIPSTOCK 7/8/2012 P86, 7,383 j* 1 Perforations & Slots ,:', IP 11 Shot PACKER, 7,397 Top (ND) Btm (TVD) Dens - Top (ftKB) Btm (ftKB) MB) (ftKB) Zone Date ( ... Type Comment GAS LIFFT. 7,534 7,578 5,950.5 5,989.5 0-4 UNIT B, 9/28/1984 12.0 IPERF Dresser Atlas ,436 IL GAS LIFT, 7,678 7,688 6,079.0 6,088.0 A -5, 2D-05 9/28/1984 4.0 IPERF Dresser Atlas 7.502 7,700 7,742 6,098.8 6,136.9 A-4, 2D -05 9/28/1984 4.0 IPERF Dresser Atlas _Ai 11 Notes: General & Safety IPERF, End Date Annotation 7,534 4 /7/2001 NOTE: BROKE OFF LATCH WHEN ATTEMPTED TO PULL DMY 7/30/2010 NOTE: TAGGED OBSTRUCTION @ 6864' 9/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 7,805 7/24/2012 NOTE: ADDED LATERALS L1, L1 - 01, L1 - 02 060 Punches, iti i r 7,816 [ # LOCATOR, �- TZI & 74 ✓ 2 0 I 7,622 I PACKER, 7,824 MILLOUT, 7,626 NIPPLE, 7,639 WHIPSTOCK, 7,639 505, 7,843 IPERF, 7,678 -7,888 IPERF, 7,700-7,742 SLOTS, 7,620-8,190 PRODUCTION, 33 -7,971 TD (2D-05), 7,990 SLOTS, 7,7829,861 SLOTS, Mandrel Details 7,860-9,910 LI, To De th To Port LINER L1, P P P 7,661 (TVD) Inc( OD Valve Latch Size TRO Run LINER ER L1 Lt -01, 7,E Stn Top (ftKB) (8103) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Cont... I- 10 LINER R L Li -02, 1 2,091.4 1,918.6 40.81 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/28/1994 7,619 10,011 II 21111 2 4,227.6 3,438.0 45.02 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/28/1994 3 5,739.4 4,538.2 41.42 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/28/1994 4 6,859.9 5,389.5 38.93 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 12/17/2006 5 7,336.5 5,777.8 30.07 OTIS OVAL 1 1/2 GAS LIFT DMY RO 0.000 0.0 10/2/1989 6 7,435.7 5,863.9 28.69 MMH FMHO 1 INJ DMY BK 0.000 0.0 11/27/2008 7 7,5024 5,922.5 27.97 MMH FMHO 1 INJ DMY BTM 0.000 0.0 6/3/2012 - - - - - -- - - 8 7,605.2 6,014.4 27.09 MMH FMHO 1 INJ DMY BRO... 0.000 0.0 10/14/2004 2D -05 Well Work Summary DATE SUMMARY • 2/25/12 WORKED TIGHT SPOT @ 7510' SLM WITH TANDEM BRUSHES & 2.68" UGE. RAN 2.62" WHIPSTOCK DUMMY TO 7700' SLM; TBG CLEAR. READY FOR CALIPER. 3/4/12 LOGGED 24 ARM CALIPER FROM TAG AT 7852' TO SURFACE. LOGGED REPEAT SECTION BELOW TUBING TAIL. RECOVERED A PIECE OF JUNK STUCK IN ELINE CENTRALIZER. SECTION OF A METAL RING (5/8" W X 3" L X 1/8" T). LOG SUBMITTED TO ANCHORAGE FRS FOR PROCESSING. 6/3/12 PULLED 1" CV @ 7484' RKB, REPLACED WITH 1" DV ( C -SANDS CLOSED) GOOD 2000 lb.TBG TEST. COMPLETE. 6/6/12 TAG BTM @ 7834' SLM EST 109' RAT HOLE, MEASURED BHP @ 7834' SLM ( 2990 Max psi ). PREFORMED INJECTIVITY TEST @ .25 BPM .5 BPM & 1 BPM. COMPLETE. 6/7/12 MIT -IA (PASSED) TO 3,000 PSI, MIT -OA (PASSED) TO 1800 PSI, T -POT (PASSED), T- PPPOT (PASSED) IC -POT (FAILED), IC -PPPOT (PASSED). 6/22/12 (PRE CTD) : PT & DD TEST ON MV PASSED, SSV PASSED & SV PASSED 6/24/12 Use 2.80" Step Mill to mill through D Nipple 0 7621' RKB. 6/25/12 Attempt to pump 23bbls neat 17.0ppg cement from PBTD and clean back out to a target depth of 7,610'. Once cement was at depth, unable to maintain even the minimum squeeze pressure of 1,050psi. Perform FCO down to 7,685 to clean out cement and will restart job in the morning with the same procedure. 6/26/12 2nd attempt at pumping 22bbls neat 17.0Ib cement and squeezing appears to have failed. Unable to maintain the mimimum squeeze pressure without pumping cement past the target depth objective of 7,610'. 6/29/12 CLEARED CEMENT STRINGERS FROM 7245' SLM. TUBING OPEN 2.77" TO 7625' RKB. TAGGED TOC © 7688' RKB. A -5 PERFS ARE OPEN. MEASURED BHP @ 7678' RKB = 3084 psi: LRS CONDUCTED INJECTIVITY TEST @ .25, .5, .75, AND 1 BBUMIN. COMPLETE. 7/1/12 Pump 15 bbls 17.0 lbs neat cement into 7" and up into 3 1/2 ". Hold target pressure for 30 minutes then clean out cement to depth of 7,610_. Maintain 1:1 returns and leave 650 psi on wellhead. 7/3/12 TAG TOC @ 7520' RKB, MIT -T TBG TO 1500 PSI, PASS; CALLED FOR BPV Pre -CTD WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 13, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 :,;,-., � , x ,,, 2 7 RE: Multifinger Imaging Tool (MIT) : 2D -05 Run Date: 7/8/2012 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 2D -05 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21157 -00 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: 907 - 273 -3535 klinton.wood@halliburton.com Date: c)/24/2_ Signed: VILL- ) • 0 ` �., - - r (� 7 a k t k � i SEAN PARNELL, GOVERNOR L Y L a J ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Dan Venhaus °--iv CTD Engineer ' ConocoPhillips Alaska, Inc. \ C 6 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2D -05 Sundry Number: 312 -209 Dear Mr. Venhaus: JUN 2 9 201 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. Sincerely, / Cath P. Foerster ,�/� Chair DATED this /4-' "aay of June, 2012. Encl. • ,. STATE OF ALASKA RECEIVED ,,, ) AIl<A OIL AND GAS CONSERVATION COMMON JUN 0 6 012 APPLICATION FOR SUNDRY APPROVALS p K I I z 20 AAC 25.280 c 1. Type of Request: Abandon r Plug for Redril' , ?Teti'. tteNew Pool r Repair w ell f Change ppr ve�Pr r r Suspend r Plug Perforations IV - /`.t ' Perforate r Rill Tubing r Time Extension r "" Operational Shutdow n Re -enter Susp. Well r` Stimulate r Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 184 -126 - 3. Address: Stratigraphic r Service �'y 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21157 -00 ` 7. If perforating, 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 r No 2D -05 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25658 . Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7990 • 6363 • 7718' 6114' 4210' Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 116' 116' SURFACE 3798 9.625 3823' 3159' I PRODUCTION 7938 7 7971' 6345' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7534' 7578', 7678' 7688', 7700' -7742' 5949'- 5988', 6076- 6087', 6098' -6136' 3.5 J -55 7625 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL HYD SET RETRIEVABLE PACKER MD= 7379 TVD= 5813 PACKER - BAKER FB -1 PERMANENT PACKER MD= 7606 TVD= 6013 SSSV - BAKER FVL SSSV MD =1870 TVD =1752 12. Attachments: Description Summary of Proposal J� 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7∎ 6/18/2012 Oil E Gas r WDSPL r Suspended • 16. Verbal Approval: Date: W � INJ o GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Venhaus @ 263 -4372 Printed Name an Ven1y26 Title: CTD Engineer t Signature 41 Phone: 263 -4372 Date 6 —5 " f - 2.. Commission Use Only Sundry Number: 3 Z 209 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 6 -- / f ,. / IP ty R AI !t/i ,Q �,r 2... Submit In Duplicate 1U�MM..'�� /� Z' 0R1G1NAL • • KRU 2D -05 CTD Summary for Plugging Sundry (10 -403) Summary of Operations: Well 2D -05 is a Kuparuk A- sand /C -sand injection well equipped with 31/4" tubing and 7" production casing. Three proposed A -sand CTD laterals will increase reservoir exposure in two adjoining fault blocks. Prior to drilling, the existing A -sand perfs in 2D -05 will be squeezed with cement to provide a means to kick out of the 7" permanently abandon only the Kuparuk A -sand. The C -sand 7 casing. This will perma y y perfs will still be accessible p p via the single selective. ConocoPhillips requests a variance from the requirements of 20 AAC ---- - ' 25.112(c)(1) to plug the perfs in this manner. i G L i a r �l7 ✓P or After plugging off the existing A -sand perfs with cement, a pilot hole will be drilled through the cement to 7670' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2D- 05L1 sidetrack will exit the 7" casing at 7637' MD and will target the A4 sand south of the existing well with a 2213' lateral. The hole will be completed with a 2 slotted liner to the TD of 9,850' MD with an aluminum billet at 7775' MD. The 2D- 05L1 -01 lateral will kick off from the aluminum billet at 7775' MD and will target the A4 sand west of the existing well with a 2100' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9,875' MD with an aluminum billet at 7855' MD. The 2D- 05L1 -01 lateral will kick off from the aluminum billet at 7855' MD and will target the A4 sand north of the existing well with a 2000' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9855' MD with the final liner top located just inside the 3Y2" tubing at 7615' MD. All laterals will be flowed back for 5 -7 days for clean up purposes. No pre - production period is planned prior to conversion to injection. CTD Drill and Complete 2D -05 Laterals: July 2012 Pre -CTD Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs — T & IC. 3. MIT -IA, MIT -OA. 4. RU slickline. Tag fill. Get updated static BHP survey. 5. Pressure test tubing to confirm that the C sand straddle has integrity. 6. RU coil. Mill out D- nipple at 7621' RKB to 2.80" ID. ph/1 Re cis 7. RU coil. Plug all perfs with cement from PBTD @ —7852' up to the tubing tail perfs at 7616' MD. RD coil. 8. RU slickline. Tag top of cement and pressure test. RD slickline. 9. Prep site for Nabors CDR2 -AC, including* catt;na RPV I - Rig Work 1. MIRU Nabors CDR2 -AC rig using 2 "coil tubing. NU 1 -1/10 bur L, 2. 2D -05L1 Sidetrack (A4 sand, south) a. Drill 2.80" high -side pilot hole through cement to 7670' MD. r / b. Drift pilot hole with whipstock dummy Page 1 of 2 June 4, 2012 • t • • c. Set whipstock at 7637' MD with high -side orientation. d. Mill 2.80" window at 7637' MD. r e. Drill 2.70" x 3" bi- center lateral to TD of 9850' MD f. Run 2 slotted liner with an aluminum billet from TD up to 7775' MD 3. 2D- 05L1 -01 Lateral (A4 sand, west) a. Kick off of the aluminum billet at 7775' MD b. Drill 2.70" x 3" bi- center lateral to TD of 9875' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 7855' MD 4. 2D- 05L1 -01 Lateral (A4 sand, north) a. Kick off of the aluminum billet at 7855' MD b. Drill 2.70" x 3" bi- center lateral to TD of 9855' MD c. Run 2%" slotted liner from TD up to 7615' MD, up inside the 3V2" tubing tail 5. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Flow well to clean up 5 -7 days 4. Return to injection AI fefelvd �c�. ski 4eGeff4if, ��lrr� h re/(s � / /e ;Irv!" o�°�� a4 /e/ -q cJ � gairpop Ow co pee tio,, Mfra �o,cr5ris k ,. 9 /4 3 , 9/ ,, Page 2 of 2 June 4, 2012 • • Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Monday, June 11, 2012 11:24 AM To: Schwartz, Guy L (DOA) Subject: Kuparuk Well 2D -05 Sundry 312 -209 Guy, Please review. Dan, We received your sundry application for Kuparuk well 2D -05 (PTD 184 -126, Sundry 312 -209). Since you plan on plugging the A sand perforations while leaving the C sand perforations open, this application should be for "plug perforations" only and not for "plug for redrill ". A variance from 20 AAC 25.112(c)(1) is not required. In order to process this sundry we will need a wellbore schematic for the existing completion and a schematic for the proposed completion. Thank you, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victona.ferquson@alaska.gov 1 • 2 ` KUP D -05 ConocoPhillips :;, wen Attributes Max Angle & MD TD Alaska, Inc. Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) Cor,ocoimdlih. 500292115700 KUPARUK RIVER UNIT INJ 46.80 3,700.00 7,990.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date Well C0n59: 2D - 05, 12/29/2011 8 00 02 AM SSSV: LOCKED OUT Last WO: 46.60 9/20/1984 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,842.0 12/28/2011 Rev Reason: GLV C /O, TAG ninam 12/29/2011 • € Casing Strings a. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 35.0 116.0 116.0 62.50 H WELDED , I Casing Description String 0... String ID ... Top (f KB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.9 21 34,9 3,832.9 3,165.2 36.00 J - 55 BTC HANGER, 33 Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 r PRODUCTION 7 6.276 33.0 7,971.2 6,345.3 26.00 J -55 BUTT Tubing Strings Tubing Description !String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING i 31/2 2.992 32.7 7,625.5 6,031.0 9.30 J -55 EUE8RD Completion Details Top Depth _. (TVD) Top Inci Nomi... CONDUCTOR, _� Top (ftKB) (ftKB) ('1 Item Description Comment ID (in) 35-116 32.7 32.7 0.40 HANGER FMC GEN III TUBING HANGER _ -_ 3.500 1,870.2 1,751.6 39.78 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 7/26/94) 2.810 7,365.5 5,801.7 30.38 PBR BAKER PBR 3.000 SAFETY e 0 , 7,379.2 5,813.4 30.14 PACKER BAKER FHL HYD SET RETRIEVABLE PACKER 3.000 1 7,521.8 5,938.3 27.76 BLAST RING 2.992 7,604.2 6,012.2 27.11 LOCATOR BAKER LOCATOR SUB w/ 5' SEALS 2.992 GAS LIFT, 7,6.06.0 6,013.8 27.08 PACKER BAKER FB -1 PERMANENT PACKER 4.000 2,074 7,608.5 6,016.0 27.04 MILL MILL OUT EXTENSION 2.992 7,621.5 6,027.4 26.82 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,624.9 6,030.4 26.76 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 7626' during SWS (PROF on 2.992 08/23/08 SVRFACE, O ther In Hole (Nireline retrievable plugs, valves, pumps, fish, etc.) 35 -3,833 Top Depth (ND) Top Inc! FISH, 4,210 j. Top (f1(13) (ftKB) 1') Description Comment Run Dab ID (In) GAS LIFT, 4,210 3,427.0 45.11 FISH STAINLESS STEEL BAND FROM HOLEFINDER APPROX 11/30/2008 0.000 4,210 3/4 ":x9 "x 1/16" III 7,616 6,022.6 26.91 TBG Punches TUBING PUNCHES shot w/2" HSD GUN HJ CHARGES 1/28/2007 2.992 GAS LIFT, 1/28/2007 5,722 Perforations & Slots Shot GAS LIFT, Dens 6.842 Top (TVD) Btm )TVD) Top (ftKB) Btrn (ftKB) (ftKB) (ftKB) Zone Dab (Ph- Type Comment 7,534 7,578 5,949.1 5,988.2 C UNIT B, 9/28/1984 12.0 IPERF Dresser Atlas GAS LIFT, 20 7,319 mts .*1 7,678 7,688 6,077.7 6,086.6 A -5, 2D -05 9/28/1984 4.0 IPERF Dresser Atlas 7,700 7,742 6,097.5 6,135.6 A-4, 2D-05 9/28/1984 4.0 IPERF Dresser Atlas PBR, 7,368 Notes: General & Safety End Date Annotation PACKER, 7,379 _ _ 4/7/2001 NOTE: BROKE OFF LATCH WHEN ATTEMPTED TO PULL DMY 7/30/2010 NOTE: TAGGED OBSTRUCTION @ 6864' GAS LIFT, 9/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 7,418 IA GAS LIFT, 7,485 at a IPERF, i 7,5347,578 - li GAS 7 .58 ],587 iii . LOCATOR, 1 7,604 PACKER, 7,606 MILL, 7,609 a I TBG Punches, et 7,616 NIPPLE, 7,621 IR 1 SOS, 7,625 Mandrel Details Top Depth Top Port (TVD) Inci OD Valve Latch Size TRO Run IPERF, Stn Top (ftKB) )ftKB) ('1 Make Model (In) Sere Type Ty On) (psi) Run Dab Com... 7,678.7,688 1 2,073.6 1,906.9 40.77 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/28/1994 2 4,209.9 3,426.9 45.11 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/28/1994 3 5,721.6 4,525.4 41.31 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/28/1994 IPERF, - . 4 6,842.2 5,376.7 39.98 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 12/17/2006 7700 - 7,742 5 7,318.8 5,762.0 31.21 OTIS HP Round 1 1/2 GAS LIFT DMY RO 0.000 0.0 10/2/1989 6 7,418.0 5,847.2 28.89 MMH MMH 1 INJ DMY BK 0.000 0.0 11/27/2008 7 7,484.7 5,905.5 28.17 MMH MMH 1 INJ CV INT 0.000 0.0 12/28/2011 8 7,587.5 5,996.6 27.06 MMH MMH 1 INJ DMY BRO... 0.000 0.0 10/14/2004 PRODUCTION, 33.7,971 TD (2D -05), 7,990 2D -05 Proposed CTD Sidetrack 3 -1/2" Baker FVL SSSV @ 1870' MD (locked out) ilia 3 -1/2" 9.3# J -55 EUE 8rd Tubing to surface 3 -1/2" gas lift mandrels @ 2073', 4209', 5721', 6842', 7318' RKB 16" 62# H-40 shoe — @116'RKB 9 -5/8" 36# J -55 shoe H.,., • @ 3823' RKB ■ Baker 3 -1/2" PBR @ 7365' RKB (3" ID) Baker FHL packer @ 7379' RKB (4.0" ID) 3 -1/2" MMH production mandrels @ 7418', 7484', 7587' RKB Baker FB -1 packer @ 7606' RKB (4.0" ID) v C -sand perfs 7534' - ■ Baker MOE @ 7608' RKB 7578' RKB — Tubing punches @ 7616 -7618' MD 3 -1/2" Camco D landing nipple @ 7621' RKB (2.75" min ID, No -Go) i - t0 be milled out to 2.80" pre -rig 2 -3/8" liner top @ l�f 3 -1/2" tubing tail @ 7626' RKB 7615' MD ,t,$ a, � 11 � ■.- Top of Whipstock © 7648' MD 2D- 05L1 -02 (north) '�- TD= 9,900'MD KOP @ 7648' MD • i . A -sand perfs (sgz'd) 7678' - 7742' RKB *1 q',- :11 ,--,-' ..-- - ------------------ ----.___________ - r. ,....„, .,...,„,„.- _ -_" - -' 2D- 05L1 -01 (west) 2D -05L1 (east) \ TD = 9,950' MD TD = 9,850' MD s Alum billet © 7855' MD Alum billet © 7795' MD 7" 26# J -55 shoe @ 7971' RKB s t...x?NNE.— • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: p� 1 ^'9 (7' INTENT PLUG for RE -DRILL WELLS V (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check�'to make sure that the "Plug for Redrill" box in the upper left corner of the 403 c form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 1� \44�03 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abarfidon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and V operator's copies). Instead, we w�F4l, check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. ��� 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code " IBPRD" into RBDMS. is code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10-417, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redri " code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a stat. s of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve wi also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Ste e does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the orm 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. ''ll change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. ill check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug ►r Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review le list of suspended wells for accu racy. Thanks, Steve D. file: //F: \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 • �� L k — 12G WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 6, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 WOWED JUL 2 2012 RE: Multifinger Imaging Tool (MIT) : 2D -05 Run Date: 3/4/2012 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 2D -05 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21157 -00 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: 907 - 273 -3535 klinton.wood@halliburton.com Date: 42-Z b 2, Signed: 1 �0 624 i ConocoPhillips aa~ka P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 1St, 2010 Mr. Guy Schwartz Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~~~~ ~iA I~ ~ ~ ~1 ~ 4~~r- ~ ~~ alb-ens Dear Mr. Guy Schwartz: 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 November 10th, 20th and 24th, 2009. The corrosion inhibitor/sealant was pumped December 29th and 30th, 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 K1 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 01/01/10 ~ Pad 20. 2C_ 2D & 3K Well Name API # 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 2A-26 50103205750000 2080940 12" n/a 12" n/a 4.25 12/30/2009 2A-27 50103206040000 2091070 36" Na 36" n/a 12.75 12/30/2009 2C-14 50029212260000 1842100 18' 2.5 50" 11/20/2009 12.32 12/30/2009 2C-15 50029212190000 1842030 SF n/a 26" n/a 4.67 12/30/2009 2C-16 50029212180000 1842020 SF n/a 33" n/a 7.22 12/30/2009 2D-02 50029211770000 1841520 SF n/a 24" n/a 4.45 12/30/2009 2D-03 50029211780000 1841530 SF n/a 24" n/a 4.67 12/30/2009 2D-04 50029211760000 1841510 SF n/a 24" n/a 4.45 12/30/2009 2D-05 50029211570000 1841260 SF n/a 24" Na 4.45 12/30/2009 2D-08 50029211580000 1841270 SF n/a 28" n/a 4.67 12/30/2009 2D-13 50029210700000 1840120 21' 3.0 27" 11/10/2009' 5.1 12/30/2009 2D-14 50029211830000 1841590 SF Na 24" n/a 6.37 12/30/2009 2D-16 50029211850000 1841610 28' 4.0 26" 11/10/2009 5.1 12/30/2009 3K-27 50029227510000 1970460 7' 1.0 12" 11/24/2009 2.97 12/29/2009 ~ ~ MEMORANDUM To: Jim Regg ~~~~ ~( l~, Zt~`1 P.I. Supervisor I FROM: Bob Noble Petroleum inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 09, 2009 SUBJECT: Mechanical Integriry Tests CONOCOPHILLIPS ALASKA INC 2D-OS KUPARiJK RIV LJNIT 2D-OS Src: Inspector NON-CONFIDENTIAL Reviewed By: P.L Suprv ~ Comm Well Name: KUPARUK RIV IINIT 2D-OS API Well Number: 50-029-21157-00-00 Inspector Name: Bob Noble Insp Num: mitRCN090906202546 Permit Number: 184-126-0 Inspection Date: 9/6/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P.T.D ZD-os ' ~g41260, Type Inj. TypeTest N SPT TVD Test psi saiz ' IA a9o zsio -i OA iao 2310 i6o - 2310 iao zsio , ~ao ~ Interval 4YRTST p~F p ~- Tubing 1420 1430 1430 1430 Notes: ti1,c~ , r ~d -I~s~- Pre~s~~~e ~ Z~g: :~~k:;` ~'<+:"' ' ~ 1:. r' . .:. i ~L:~~ ~:~ , Wednesday, September 09, 2009 Page 1 of 1 • MEMORANDUM To: Jim Regg `~ P.L Supervisor ~~jC~ ~ ~~h /~ ll FROM: John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 26, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2D-OS KUPARUK RIV UNIT 2D-OS Src: Inspector NON-CONFIDENTIAL Reviewed By~ P.I. Suprv ~ " Comm Well Name: KUPARUK RIV LTNIT 2D-OS Insp Num: mitJCr090823164548 Rel Insp Num: API Well Number: 50-029-21157-00-00 Inspector Name: John Crisp permit Number: 184-126-0 Inspection Date: g~21/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zD-os TYPe Inj. rr ( T~ ss~z ~ IA ~o P.T.DI lsa~z6o TypeTest SpT Test psi isoo ' pA ~ao Interval a~TST p~F F ~ Tubing ~aoo NOteS: ~ bbls pumped away to achieve 700 psi. Stopped pumping & presure fell to 70 psi. Fail MIT. ;~ r ~ ~.13;~.i Wednesday, August 26, 2009 Page 1 of 1 ~i~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # f t~~ 1 ~~,Jf~ 0 ~ 20Q9 ~ <~6~ X01180 ~~°s~'i~~~i* c~ra~-~~I~~ ..~ rs , ~,_ 1' ~~' -~ ~~ 2~f' Log Description NO. 5261 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/03/09 2U-15 AZCM-00012 GLS 03/28/09 1 1 3G-12 B04C-00047 INJECTION PROFILE - ~- j // 05/10/09 1 1 1C-172A 604C-00049 GLS 05/11/09 1 1 3G-11 B04C-00050 PRODUCTION PROFILE 05/12/09 1 1 2A-06 8148-00048 DDL - 05/15/09 1 1 2A-16 B14B-00047 LDL - 05/15/09 1 1 3G-16 B14B-00049 INJECTION PROFILE 05/16/09 1 1 3G-18 B14B-00050 PRODUCTION PROFILE 05/17/09 1 1 2D-05 AYS4-00072 INJECTION PROFILE - 05/21/09 1 1 1 E-15 8146-00058 LDL - 05/24/09 1 1 3H-33 B04C-00006 CH EDIT (PEX,SONIC SCANNER,CHFR) 02/09/09 4 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. U ~J J o~ p~~~~, ~~ I" i~ ~~~~II1~G~fi Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ,~ ;, `"'~"~~' ~ ~~ ~ ~~ 200 ~`~ ~a Log Description 09/05/08 NO. 4861 ~ { Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Beluga River Unit Date BL Color CD iJ-127 12096529 INJECTION PROFILE ~ - ~ ~ 08/14/08 1 1 1 R-11 12096530 PRODUCTION PROFILE 'y-- 08/15/08 1 1 iJ-118 12066541 MEM INJECTION PROFILE - 08/17/08 1 1 iJ-122 12066542 MEM INJECTION PROFILE /(p 08/18/08 1 1 2D-09 11978477 PRODUCTION PROFILE (p 08/18/08 1 1 2B-14 119966275 PRODUCTION PROFILE / ~(- r (Q 08/19/08 1 1 iJ-105 12066543 MEM INJECTION PROFILE aQ'}- /(p 08/19/08 1 1 2E-12 11996653 SBHP SURVEY C ( ~ 08!21/08 1 1 iJ-156 12080419 _ INJECTION PROFILE ( 08/21/08 1 1 1A-26 12080420 SBHP SURVEY ~Q -( S 08/22/08 1 1 1A-23 12080421 SBHP SURVEY ( ~ ` 08/22/08 1 1 D-05 12080422 INJ PROF/LDL ~ ,((p 08/23/08 1 1 iH-11 12080423 PRODUCTION PROFILE 08/24/08 1 1 2B-03A 11996656 PRODUCTION PROFILE ( 08/24/08 1 1 3C-17 11996658 PERF/SBHP SURVEY app- l(p / 08/26/08 1 1 2M-11 12080427 PRODUCTION PROFILE / = ~ $-Q 08/28/08 1 1 1Y-21 11996662 PRODUCTION PROFILE / '- O~ ~lq 08/30/08 1 1 2E-13 12080431 SBHP SURVEY G - G 08/31/08 1 1 2E-14 12080432 SBHP SURVEY L[•- 08/31!08 1 1 1 B-13 11996664 PRODUCTION PROFILE ~ 09/01/08 1 1 iH-18 11996666 INJECTION PROFILE ~/ 09/03/08 1 1 9 F-10 11996660 PLUG SETTING RECORD 08/28/08 1 1 iG-05 11996665 PACKER SETTING RECORD 09/02/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • ~®~~~ TO: Jim Regg ~ P.I. Supervisor (1 ~~`l ~lC FROM: 13ob Noble Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 08, 2008 SUBJECT: Mechanical Inteb~ityTests CONOCOPHILLIPS ALASKA INC 2D-OS KUPARUK RIV UNIT 2D-OS Src: [nspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ,_j~~ Comm Well Name: KUPARUK RN UNIT 2D-OS Insp Num: mitRCN080707075415 Rel Insp Num: API Well Number: 50-029-21157-00-00 Permit Number: 184-126-0 Inspector Name• Bob Noble Inspection Date: 7/52008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ' zD-os Type Inj. N TVD ssl3 ~ IA X60 % zzso z26o j zzso j I p•T i 1841260 TypeTest ~ SPT' Test psi ;, zzso i pA ~ I6o tso lso ~ Iso Interval aYRTST p~F P Tubing ~~ zio no ~ 7to Notes: ,ELI r~ . ~~7- ~!~~L ~rL'r ~'~C:i.~(.x:i ~~~~~ A L' ~ ~ ~a Tuesday, July 08, 2008 Page 1 of 1 2D-OS WAG injector, PTD # 184-126, notice of injection results Page 1 of 1 • Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] / /' Sent: Monday, June 23, 2008 5:43 AM ? ~o~v~ ~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; CPF2 Prod Engrs Subject: 2D-05 WAG injector, PTD # 184-126, notice of injection results Attachments: 2D-05.pdf; 2D-05 90 day TIO plot.jpg Tom & Jim, On 4/30/08 AOGCC approved 30 days of injection into 2D-05 for testing and monitoring purposes, the well was placed on injection 5/20/08. 2D-05 was identified and reported in 2007 as having suspect T X IA while in MI service. 2D-05 has shown no signs of communication during the recent injection test. A leak detect /injection profile was performed of 6/19/08. The log was performed with 2600 psi injection pressure and all fluids were entering the A sands. have enclosed a 90 Day TIO plot and well bore schematic for your convenience. CPAI would like to continue injecting into 2D-05 and treat it as a normal injector at this time. We will report any ,- future mechanical integrity issues per rule 7. 2D-05 is currently on the monthly report. I propose leaving it on the report through July and then removing it ` assuming no change in the mechanical integrity of the well. Please respond with regard to our proposed plan forward. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 «2D-05.pdf» «2D-05 90 day TIO plot.jpg» ~c~r~4~~~~% AUC ~ ~' ZD~ 7/30/2008 KRU 2D-OS PTD 184-126 0. 0. Ct . 0. 0. 0_ Q. 0. zloo leoo lsoo lzoo 900 600 300 0 PICK TINE 22-J UN-08 14:57:2? ~~(; T1G N~IIE DESCRIPTION t'-Vd1.OF: LATEST ~ WL2D-05-CHORE FLOW TUBINO CHORE ??????7 ~ SCRATCH 33 FLOW TUHIN(3 PRESSURE 7777777 SCRATCII_33 FLOW TUBINO TEMP ???7??? ~ 7777777 der a77?77? ~ SCRATCH_33 INNER ANNULUS PRES 77???7? ~ SCRATCH_33 OUTER ANNULUS PRES 7777777 • PL(')"I" [lUt'.ATIpN PLf1T ~:N[7 "t'iM(': +0216D:00:00 tur,23-JUN-08 05:31 DRILLSITE WELL PREV WELL 2D 05 NEXT WELL ENTRY "I"YI'F: OPERATOR OPERATOR VERIFIED ~ aYtSTEM AUTO ENTRY ~ BOTH PLOT S;TAR':C TIME MINOR TIME 25-MAR-D8 05:31 MAJOR TIME WEER r ~ _ ~~~ - ~ ~ ~ 1 ~Qn~~ I: ~f ~(11(~'~ well G-' fS200&SA32]FM--- ~J S ~ ~~ 1 Conductor I sssv ~ , 1,670 o GAS LIFT, 074 2 , ~ sudaca ~ GAS LIFT, I a.21o ` GAS LIFT, - ~~~~ s.nz ~ -w~ I I GAS LIFT, y 6,842 GA6 LIFT, ~ 7,319 { - 1 PBR, 7.366 '. PACKER, _ - -- --~ - __-/ --`~~ 7,379 g i JECTION, _ t 7,418 JECTION, - ],485 ,534-7,576, 1 ' j 9/28/1984 1 _ ~~ JECTION, 7,587 PACKER, • _ ,' ~ -~ 7,606 . . / TBG I Punches, - 7,616 [ I NIPPLE, f yyy~~~ ~. 7,621 tf SOS, 7,625 ~ - ~ i. TTL, 7,626 4 4 700-7,742, 9/28/1984 ~ - Production TDB (zD-os), 7,990 P 2D-05 Wellbore API/UWI Fteltl Na:i~o ": i..ll Status Maximum I ehnanon (") ITOteI Depth (ftKB) 500292115700 KUPARUK RIVER UNIT INJ 46.80 7 990.0 Comment K2a (ppm) Dafe A n t t on End Date KB-0rd (ft) Rig Release Date LOCKED OU7 LastWO: 46.60 9/20/1984 Annotation Depth (HKB) End Date Annotation T 7 701 R /O ~ L 0 6 End Date ast ao: . /12/2008 Rev eason: TAG, GLV C 6/15/2008 Casino Desenonon I OD hnl I ID hnl I Too IitKBI ISat Depth IftKB115e1 Depth ITVDI IhK611 Wt llbs/ft11 Gr ade 1 Too Threatl I l bn i Da. ~i~ :,I T I I H':'. ~ I F~ih ii~H Yi I~~F,fn I .C I F ~. V. I , t ,~. ICI I. i~~..~. IBIN I ~ -I I - - - lop (nKB) 1,870.0 Desenpbon SSSV comment LOCKED OUT Baker'FVL' (Locked Out 7/26/94) Run Ww 9/2S/1984 4u li:f) 2.810 2,074.0 GAS LIFT MMH/FMHO/1/DMY/BK-2/// Comment: STA 1 9/28/7994 2.867 4,210.0 GAS LIFT MMH/FMHOl1/DMY/BK-Z///Comment: STA2 9128/1994 2.867 5,722.0 GAS LIFT MMH/FMHO/1/DMY/BK-2//I Comment: STA3 9/28/1994 2.867 6,842.0 GAS LIFT MMH/FMHOl1/DMY/BK-2///Comment: STA4 12/1712006 2.867 7,319.0 GAS LIFT OTIS/HP Round/1.5/DMY/RO/// Comment: STA 5 10/2/1989 2.907 7,366.0 PBR Baker 10 9/28!1984 3.000 7,379.0 PACKER Baker'FHL' hyd set PERM 9/2817984 3.000 7,418.0 INJECTION MMH/MMH/1/DMY/BK/// Comment STA 6 6/i2f2008 2.867 7,485.0 INJECTION MMH/MMH/7/DMY/BTM/.185// Comment: STA 7 1/26/2007 2.867 7,587.0 INJECTION MMH/MMH/1/DMY//// Comment: LATCH BROKEN OFF WHEN ATTEMPT MADE TO PULL DMV 4/7/2001 STA 8 10/14/2004 2.867 7,606.0 PACKER Baker'FB-1' 9/28/1984 4.000 7,616.0 TBG Punches TUBING PUNCHES shot w2" HSD GUN HJ CHARGES 1/28/2007 128/2007 2.992 7,627.0 NIPPLE Camco'D' Nipple NO GO 92S/1984 2.750 7.625.0 SOS Baker 928/i984 2.992 7,626.0 TTL 9/28/1984 2.992 sl ToP (TVD) Bim ITVDI De 1 yShot (ftKBI Btm IftK61 (ftK8) (ftKB) Tvoe Zone (h t... Total Date Commenl z NO.4759 ~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # f`. 'd ~~ i ~~ ! I Log Description ~$~,a.~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 't00 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/25/08 i G-14 11964620 INJECTION PROFILE - •°+`:? ... {e~a a a~ ear •' °~~l'~1 06/13/08 1 1 3A-i6 11964621 LDL _ ~ ~ r • ~ sa ` 06/14/08 1 1 1 B-14 12061702 LDL ~ !-~~-- ~°~'C,~ of ~~- aw ~^ 06/15/08 1 1 2N-327 12061704 PRODUCTION PROFILE Q;~,~ - -- fir'-°'-~ F'r ~-` ~°~- 06/17/08 1 1 1 B-04 12061705 INJECTION PROFILE •°°' ~ ~~ ~ -:, :~ "- t""/' .~° ~%. ~''~ 06/18/08 1 1 2D-05 11964625 INJECTION PROFILE/LDL ~-'- - n. .J-'(. ~ 06/18/08 1 1 1 E-12 11964628 G LS ~ ~~ `•~ ~ ~`~ ~ ~'} ~' ~, ~ "~ y' ~ 06/20/08 1 1 3A-06 12061708 INJECTION PROFILE I ~""`~~ / ~°~ ~ --$ ;),:~ z"~~ `~~±,~ 06/21/08 1 1 2A-08 11964629 INJECTION PROFILE d„~;~~ -~; • ~'.{mj f~-.-~=; `~ 06/21/08 1 1 i L-11 11964630 PRODUCTION PROFILE ' ~~ - ~,'~`-+~`"° 06/23/08 1 1 ~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • ~t ir_ur ua ua>. c.i rr uava aa~~vaavaa aaaav t CL~IJ 1 Vl/L • G J ~~. Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, May 20, 2008 3:13 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: Kuparuk 2D Water injection line Jim, The approved we(Is mentioned have been returned to water injection as foNows: 2D-02 - BOI on 05f 17/08 at 08:30. Q~ ~ `84 - - 7-z- 2 - - 7/08 ~ 14~A - l 51 2D-45 - BOI on 05f19108 at 07:28. ~~ i$4 _ I z~ Diagnostic testing and monitoring will be conducted during the 30 day test period. The results will be reported to the AOGCC followed by any appropriate paperwork. Please let me know if you have any questions or need any more information. Brent RogerslMartin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~~NEi~ JUN ~ ~ 2D0~ From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, April 30, 2008 1:55 PM To: NSK Well Integrity Proj; NSK Problem Welt Supv Cc: Maunder, Thomas E (DOA) Subject: RE: Kuparuk 2D Water injection line You are authorized to inject as outlined below to complete dia ostic testing and prepare your action plan. Please provide copies of'the diagnostic MITs mentioned in ur email. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [ ailto:N1878@conocophillips.com] Sent: Tuesday, April 15, 200 :30 PM To: Regg, James B (DOA); sunder, Thomas E (DOA) Ce: NSK Problem Well S v; NSK Wel! Integrity Proj Subject: Kuparuk 2D ater injection line 6/5/2008 Kuparuk 2D Water injection line Page 1 of 2 Regg, James B (DOA) • • From: NSK Problem Welt Supv [n1617@conocophillips.com] Sent: Thursday, May 01, 2008 2:32 PM ~~~ ~ li ~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: Kuparuk 2D Water injection line Attachments: MIT KRU 2D-02 05-22-06.x1s; MIT KRU 2D-04 01-17-08.x1s; MIT KRU 2D-05 08-11-07.x1s Attached are the requested MIT reports. Contact me at your convenience if you have questions or comments. Martin Martin Walters 1 Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cel I 907-943-17201 1999 Pager 907-659-7000 #909 1, ~~NE~ MAY ~ ~ 2008 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, April 30, 2008 1:55 PM To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: RE: Kuparuk 2D Water injection line You are authorized to inject as outlined below to complete diagnostic testing and prepare your action plan. Please provide copies of the diagnostic MITs mentioned in your email. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, April 15, 2008 2:30 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: Kuparuk 2D Water injection line Jim, The produced water injection line to 2D pad has been shut down for repairs since June 2006. Repairs are currently in progress with an expected completion date of 27APR08. At that time produced water injection capabilities will be restored to the pad. Just before and during the time of the water line shut down, three wells were reported with suspect TxIA communication. 5/1/2008 Kuparuk 2D Water injection line Page 2 of 2 2D-02 (184-152) 2D- 4 184-151) 2D-05 (184-126) ue to the lack of injection water, build up rate (BUR) and trending diagnostics were not completed and the suspected leaks were not confirmed. Each well has however passed a diagnostic MITIA. At the completion of the water line repairs, ConocoPhillips requests approval to bring the above listed wells on produced water injection for 30 days for additional diagnostics and BUR TIO trending. Due to the lengthy shut in, a 30 day injection period is requested to adequately allow each well to come up to operating temperature throughout the well bore and become thermally stable before BUR TIO trending. If any of the wells indicate TxIA communication before the 30 days has passed it would be shut in and the AOGCC notified. At the end of the 30 days ConocoPhillips would present the AOGCC with the status and an action plan for each well. The action plans could included applying for an AA, 10-403 for repair, or returning the well to normal status depending on the test results. Please let me know if any additional information is required to gain approval for the 30 day injection period. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 5/1/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@ataska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov ~~i ~~ OPERATOR: ConocoPhillips Alaska Inc. ~~~ FIELD !UNIT /PAD DATE: OPERATOR REP: AOGCC REP: Kuparuk / KRU / 2D-05 08/11 /07 Colee /Johnson - AES Packer De th Pretest Initial 15 Min. 30 Min. Well 2D-OS T e In~. W TVD 5,813' Tubin 1,625 ,725 1,725 1,725 Interval O P.T.D. 184126 T etest P Test si 1500 Casin 1,775 2,500 2,475 2,460 P/F P Notes: Diagnostic MITIA OA 185 185 185 185 Well T e Inj. TVD Tubin Interval P.T.D. T e test Test si Casin P/F Notes: OA Well T e In~. TVD Tubin Interval P.T.D. Ty e test Test si Casin P/F Notes: OA Well T e In~. TVD Tubin Interval P.T.D. T e test Test si Casing P/F Notes: OA Well T e In'. TVD Tubing Interval P.T.D. T e test Test si Casin P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL. Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11/27/07 2007-0811_MIT_KRU_2D-OS.xis i~uNcu ui~ c,t~ vvuwi ui~w~tvii 1111\. • ' Regg, James B (DOA) • t~ ~R ~_ .~ _ ~_ . ~,e ._~.~a~~ ~~__ ..~a~~~.~ ,.~~ From: Regg, James B (DOA) (~ Sent: Wednesday, April 30, 2008 1:55 PM ~J L~~ ~ a~ ~~%~~: To: 'NSK Well Integrity Proj'; NSK Problem Well Supv ~ ~ ` i ~- Cc: Maunder, Thomas E (DOA) Subject: RE: Kuparuk 2D Water injection line You are authorized to inject as outlined below to complete diagnostic testing and prepare your action plan. Please provide copies of the diagnostic Mils mentioned in your email. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~~+~~iV~~ M~~' ~ ~ 2008 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, April 15, 2008 2:30 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: Kuparuk 2D Water injection line Jim, ra~C i s~r~ ~~~ t`-~ The produced water injection line to 2D pad has been shut down for repairs since June 2006. Repairs are currently in progress with an expected completion date of 27APR08. At that time produced water injection capabilities will be restored to the pad. Just before and during the time of the water line shut down, three wells were reported with suspect TxIA communication. 2D-02 (184-152} 2D-04 184-151) 2D-05 (184-126) ~=~ue to the lack of injection water, build up rate (BUR) and trending diagnostics were not completed and the suspected leaks were not confirmed. Each well has however passed a diagnostic MITIA. At the completion of the water line repairs, ConocoPhillips requests approval to bring the above listed wells on produced water injection for 30 days for additional diagnostics and BUR TIO trending. Due to the lengthy shut in, a 30 day injection period is requested to adequately allow each well to come up to operating temperature throughout the well bore and become thermally stable before BUR TIO trending. If any of the wells indicate TxIA communication before the 30 days has passed it would be shut in and the AOGCC notified. At the end of the 30 days ConocoPhillips would present the AOGCC with the status and an action plan for each well. The action plans could included applying for an AA, 10-403 for repair, or returning the well to normal status depending on the test results. Please let me know if any additional information is required to gain approval for the 30 day injection period. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 4/30/2008 I ~L-V""I - L....... . STATE OF ALASKA. MAR 0 9 2007 ALASKA Oil AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission WELL COMPLETION OR RECOMPLETION REPORT AND4wCIi)CiJe 1a. Well Status: Oil 0 Gas U WDSPL 0 Plugged 0 Abandoned 0 20AAC 25.105 No. of Completions WAG 0 Suspended 0 20AAC 25.110 Other GINJ 0. 2. Operator Name: WINJ 0 5. Date Comp., Susp., J or Aband.: September 28, 1984 6. Date Spudded: September 9,1984 7. Date TD Reached: September 17, 1984 8. KB Elevation (ft): ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 168' FSL, 550' FEL, Sec. 23, T11 N, R9E, UM At Top Productive Horizon: 1351' FNL, 1365' FWL, Sec. 24, T11N, R9E, UM Total Depth: , 126' RKB 9. Plug Back Depth (MD + lVD): 7718' MD 16114' TVD 10. Total Depth (MD + lVD): , 7990' MD 16361' TVD ' 1171' FNL, 1434' FWL, Sec. 24, T11N, R9E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529214 ' y- TPI: x- 531112 y- Total Depth: x-531180 y- 18. Directional Survey: Yes 0 No 0 5954367 ./ 5958135 5958315 Zone- 4 Zone- 4 11. Depth where SSSV set: 1870' Zone- 4 19. Water Depth, if Offshore: N/A feet MSL 21. Logs Run: 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH lVD TOP BOTTOM TOP BOTTOM Surf. 116' Surf. 116' Surf. 3823' Surf. 3159' Surf. 7971' Surf. 6345' 12.25" 8.5" HOLE SIZE CASING SIZE WT. PER FT. GRADE H-40 J-55 J-55 16" 62.5# 9.625" 36# 7" 26# 23. Perforations open to Production (MD + lVD of Top and Bottom Interval, Size and Number; if none, state "none"): 24. SIZE 3.5" 7534'-7578' MD 7678'-7688' MD 7700'-7742' MD 5949'-5988' TVD 6078'-6087' TVD 6097'-6136' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7700'-7742',7678'-7688',7534'-7578' 50 bbls CaC03 LCM Production for OIL-BBL GAS-MCF Test Period --> SI ' Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF. WATER-BBL press. psi 24-Hour Rate -> SI 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of 011, gas or water (attach separate sheet, if necessary) S"bm,~,",,,,;f"oo.,'tate"OO"'" ~ ~. ~;;:~ CG &;AHNEt> MAR 2 1 2007 NONE, 4v 1. ~/Ã/~ - . ð - . ~ q,..., /()- qo 7 _ . If ÆJtv g/~/ò 7 26. Date First Production shut-in Date otTest PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Hours Tested MI gas injector WATER-BBL 1 b. Well Class: Development 0 Exploratory 0 Service 0 - Stratigraphic TesD 12. Permit to Drill Number: 184-126 1 306-377 13. API Number: 50-029-21157-00 14. Well Name and Number: 2D-05 15. Field/Pool(s): Kuparuk River Field Kuparuk River Oil Pool , 16. Property Designation: ADL 25658 17. Land Use Permit: ALK 2584 20. Thickness of Permafrost: Ipprox 1500' MC CEMENTING RECORD AMOUNT PULLED 24" 224 sx Cold Set II 1075 sx AS III, 685 sx Class G 625 sx Class G TUBING RECORD DEPTH SET (MD) 7626' PACKER SET 17379',7606' CHOKE SIZE GAS-Oil RATIO OIL GRAVITY - API (corr) OR'GII~AL CONTINUED ON REVERSE ~ ,,3./'- ..07 R8DMS 8Ft MAR 2 0 20D7 ~ J /f6107 Form 10-407 Revised 12/2003 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2D-05 Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand 7533' 7553' 7665' 7796' 5947' 5965' 6065' 6183' N/A 30. LIST OF ATTACHMENTS Summary of Daily Opera 'ons 31. I hereby certify that the f oing is true and correct to the best of my knowledge. Contact: G. Eller @ 263-4172 Title: Phone Wells Group Enaineer Date --=s.\q \ Q 1 ¿~"s - ð.,\\ L Prepared by Sharon Allsup-Drake 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 . . ConocoPhiUlps Alaska, Inc. KRU 2D-05 ~ .~ . . API: 500292115700 Well Type: INJ Anale (ci) TS: 28 dea (ci) 7532 SSSV Type: TRDP Orig 9/20/1004 Angle @ TO: 23 deg @ 7990 sssv Completion: (1870-1871, Annular Fluid: Last W/O: Rev Reason: CIO CVs, TAG 00:3.500) FILL, PULL PLUG Reference Loa: Ref LOQ Date: Last Uodate: 1/29/2007 Last Taa: 7718' TO: 7990 ftKB LastTaa Date: 11/29/2006 Max Hole AnQle: 47 dM 3700 Description Size Top Bottom lVD Wt Grade Thread CONDUCTOR 16.000 0 116 116 62.50 H-40 SUR. CASING 9.625 0 3823 3159 36.00 J-55 PROD. CASING 7.000 0 7971 6345 26.00 J-55 .tiff ,)( ,.~~ , Size Top I Bottom I lVD I Wt I Grade I Thread I 3.500 0 I 7626 I 6031 I 9.30 I J-55 I EUE 8RD I Ii·" 4:;é" Interval lVD Zone Status Ft SPF Date Tvpe Comment 7534 - 7578 5949 - 5988 C"4,UNIT 44 12 9/28/1004 ¡PERF Dresser Atlas B 7678 - 7688 6078 - 6087 A-5 10 4 9/28/1004 IPERF Dresser Atlas 7700- 7742 6097 - 6136 A-4 42 4 9/28/1004 IPERF Dresser Atlas 1I.lIlt. . ";':1111 St MD lVD Man Mfr Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Cmnt 1 2074 1907 MMH FMHO DMY 1.0 BK-2 0.000 0 9/28/1004 2 4210 3427 MMH FMHO DMY 1.0 BK-2 0.000 0 9/28/1004 3 5722 4526 MMH FMHO DMY 1.0 BK-2 0.000 0 9/28/1004 4 6842 5376 MMH FMHO DMY 1.0 BK-2 0.000 0 12/17/200 5 7319 5762 Otis HP Round ... DMY 1.5 RO 0.000 0 10/211989 ,,:,1·.··: PSR St MD TVD Man Mfr Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv (7366-7367, Cmht 00:3.500) 6 7418 5847 MMH MMH FMHO OPEN 1.0 BK 0.188 0 1/2612007 Open 7 7485 5906 MMH MMH FMHO DMY 1.0 BTM 0.188 0 1/2612007 Open 8 7587 5996 MMH MMH FMHO DMY 1.0 0.000 0 1 0I14/200~ (1) .. PKR- 1. LA TCH BROKEN OFF WHEN A TTEMPT MADE TO PULL DMY 417/2001 (7379-7380, , 00:6.151) 4>t>t:J Deoth lVD Tvoe Description ID 1870 1751 SSSV Baker 'FVL' (Locked Out 7/26/94) 2.810 7366 5802 PBR Baker 10 3.000 Injection 7379 5813 PKR Baker 'FHL' hvd set PERM 3.000 MandrelNalve 7606 6013 PKR Baker 'FB-1' 4.000 6 (7418-7419, 7621 6027 NIP Cameo '0' Nioole NO GO 2.750 7625 6030 SOS Baker 2.992 7626 6031 TTL 2.992 -- - - - -.- - - - - - PKR (7606-7607, 00:6.151) ~I)\t.. '. ~ I I \\<:>\~ ~o\ '"' \v.\;\"'~ ~~\ ~\~~ l~\\o ·l~\~ \V\~ ..... NIP I- (7621-7622, IL \,?.~\û,. 00:3.500) TUSING (0-7626, 00:3.500, 102992) Perf - - (7678-7688) - - - -. Perf = -= (7700-7742) - - - - . 2D-05 Well Events Summary . DATE Summary j 11/4/06 MITIA PASSED, POT & PPPOT-T & IC PASSED, DRAWDOWN ON MV & SV FAILED (PRE CTD PREP) 11/5/06 MITOA PASSED, DD & PT ON MV FAILED RETEST, DD & PT ON SV PASSED RETEST. BOTH VALVES WERE SERVICED OVERNIGHT (PRE CTD) 11/29/06 DISPLACED TBG W/ 130 BBLS TO DISPLACE MI GAS FROM WELL BORE. TAGGED FILL @ 7718' RKB. ESTIMATE 24' OF FILL. PULL 1" CV's @ 7418' & 7485' RKB, NO EROSION. SET DV's IN THE SAME. IN PROGRESS. 12/1/06 BRUSHED & FLUSHED D NIPPLE @ 7621' RKB. SET 2.75" CA-2 PLUG @ 7621' RKB. TBG PRESSURE FELL FROM 1300 PSI TO 800 PSI AFTER SET, INDICATING A SANDS ARE ISOLATED. ATTEMPT TO MIT TBG TO 2500 PSI, FAILED. RAN PONY TAIL FOUND LEAK IN STN # 8 @ 7587' RKB (DV W/ 12/7/06 ATTEMPTED TO PERFORM STATIC SURVEY AT 7550' AND 7450'. COULD NOT GET GOOD STOP COUNTS DUE TO INSTABILITY OF THE WELL. PERFOMED JEWELRY LOG OVER GLM'S AND POOH. NOTED LARGE TEMPERATURE CHANGE AROUND INJECTION MANDRELS AT 7485' AND 7418', POSSIBLY DUE 12/8/06 LEAKING TREE VALVES. JOB SUSPENDED DUE TO WEATHER. 12/9/06 WEATHER DELAYED START. TESTED WRP 3000 PSI, PASSED. BLED TBG TO 300 PSI. GAUGED TBG TO 2.85" TO 1870' RKB. SET 2.81" BAKER M-1 PLUG @ 1870'. SET 3" SLIP STOP @ 1868'. 12/15/06 PULLED SLIP STOP & EQUALIZED PLUG @ 1870' RKB. IN PROGRESS. 12/16/06 PULLED M-1 PLUG IN SSSV @ 1870' RKB. SET CATCHER ON WRP @ 7400' ELM. PULLED DV @ 6842' RKB. IN PROGRESS. 12/17/06 LOADED TBG & I/A WITH INHIBITED SW & DIESEL FP. SET DV @ 6842' RKB. TESTED TBG & I/A 2500PSI, GOOD. BAILING FILL ON CATCHER @ 7400' ELM. IN PROGRESS. 12/18/06 BAILED ON & PULLED CATCHER @ 7400' ELM. SET BAKER M-1 PLUG IN SSSV @ 1870' RKB. WELL SECURED FOR TREE MAINTENANCE. 12/29/06 DD AND PT MV PASSED (PRE-CTD) 12/30/06 EQUALIZED M-1, 2 ATTEMPTS TO PULL M-1 @ 1870' RKB, IN PROGRESS. 12/31/06 UNIT ON STANDBY WAITING FOR SLlCKLlNE TO PULL WRP. 12/31/06 PULL TBG STOP & M-1 PLUG @ SSSV NIPPLE, MAKE ATTEMPTS TO PULL & BAIL SCALE OFF WRP @ 7400' ELM. IN PROGRESS. 1/1/07 WRP RENTAL FOR JANUARY. CHARGES FROM JAN 1-19. PULLED ON 1/19/07. 1/4/07 BAILED FILL @ 7387' WL. ATTEMPTED PULL WRP. IN PROGRESS. 1/6/07 BAILED FILL @ 7387' SLM. ATTEMPTED EQUALIZE WRP. IN PROGRESS. 1/7/07 WEATHER-DELAYED START. BAILED FILL @ 7387' SLM. ATTEMPTED PULL WRP. IN PROGRESS. 1/8/07 ATTEMPTED PULL WRP @ 7372' SLM. IN PROGRESS. 1/9/07 WEATHER-DELAYED START. ATTEMPTED PULL WRP. IN PROGRESS. 1/10/07 ENCOUNTERED HYDRATES @ 2110' SLM, UNABLE TO WORK PAST. JOB SUSPENDED. 1/15/07 Drift tubing with 2.80" junk mill down to 3000' CTMD with no ice plug encountered. Attempted to inject into well without success. RIH with 2.5" G-Spear and hit 55 jar hits while working up to 15K over-pull. Decision was made to release from WRP before ....... 1/16/07 PUMPED 11.5 BBLS OF 15% HCI ACID ON TOP OF STUCK WRP. AFTER SOAKING'" FOR 15 MINUTES WHP DROPPED FROM 2000# TO 1150#. ABLE TO SUCCESSFULLY PUMP THROUGH PLUG. LATCHED WRP @ 7417' CTMD. CAME FREE AFTER PULLING 27,000# (14,000# OVER). AT SURFACE WITHOUT . 2D-05 Well Events Summary . 1/17/07 ATTEMPT TO PULL WRP AT 7417' CTMD. LATCH INTO FISHING NECK AND HIT 40 JAR LICKS WITH DAILEY DUAL ACTING OIL JARS PULLING 15K# TO 20K# OVER. SWAP OVER TO 2.125" BAKKE HAMMER. HAVING DIFFICULT TIME KEEPING BAKKE HAMMER FUNCTIONING PROPERLY. STRAIGHT OV 1/18/07 RAN 3.5" OM-1 KOT W/1.70" LIB TO STA#5= LOCATE AND SD @ 7317' SLM GOOD CHINA CAP ON LIB 2' CORRECTION ***JOB IN PROGRESS*** 1/19/07 PULLED 3.5" WRP @ 7387' RKB (HURRAH!) 1/22/07 RECORD STATIC BHP OF C-SANDS STRADDLE ASSY. BAIL ON PLUG @ 7621' RKB *** JOB IN PROGRESS*** 1/23/07 PULLED CA-2 PLUG @ 7621' RKB, THEN SET CA-2 PLUG BODY W/ HES QUARTZ GAUGES @ 7621' RKB *** JOB COMPLETE*** 1/26/07 PULLED 2.75" CA-2 PLUG WITH HES QUARTZ GAUGES FROM "D" NIPPLE @ 7621' RKB.PULLED 1" DUMMY VALVE FROM STA#6 @ 7418' RKB.OPEN POCKET.NOTE...SWAB HAS HISTORY OF LEAKING. 1/27/07 DRAWDOWN & PT ON MV PASSED, DRAWDOWN ON SV PASSED, PT ON SV FAILED (PRE CTD TESTING) 1/28/07 PERFORATED 7616' - 7618' WHICH PUT 13 HOLES IN THE 8' PUP JOINT IMMEDIATELY ABOVE THE D NIPPLE USED A 2" HSD GUN, LOADED 2' WITH HYPERJET CHARGES, EH= 0.33", PENT= 9.6" 1/29/07 FULL BORE PUMP CaC03 (SAFE-CARB) PILL. PUMP 50 BBLS OF MI SAFE-CARB PILL (FORMULATED AS PER PROCUEDURE A & C SAND PILL MIXTURE- MIXED AT MI AND TRUCKED TO LOCATION JUST PRIOR TO JOB- TOTAL CARBONATE 150 LB/BBL), CHASE PILL WITH 35 BBLS DIESEL. APPROX 10 BBLS PILL SQUEEZED AWAY AT MAX PRESSURE OF 1250 PSI. '" RE: 2D-05 Plug A sand perfs . . Torn - I know the 10-403 þas been approved, but I told you that I would give you some more details about the A Sand plugback in 2D-05. Attached is a draft procedure that I wrote Friday for 2D-05. See if this doesn't answer most of your questions. We're replacing leaking tree valves currently, so I expect to begin these ops this week. -Gary -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.3tate.ak.us] ~-~ --~----- Sent: Wednesday, December 06, 2006 10:56 AM To: Eller, J Gary Subject: 2D-05 Plug A sand perfs Gary, I am looking at your proposal and have a couple of questions. 1. How firm is the start date of 12/15? If this issues on Monday will that meet your schedule? 2. While I was able to assess what you plan, a little more detail would be appreciated. In particular, the planned cement yields/volumes should be included. 3. How will you accomplish the pressure test with the C sand open above the top of cement? Thanks in advance for your reply. Torn Maunder, PE AOGCC Call or message with any questions. 2D-05 Pre-CTD prog 12-15-06.doc Content-Description: 2D-05 Pre-CTD prog 12-15-06.doc Content- Type: applicationlmsword Content-Encoding: base64 1 of I 3/19/20072:08 PM . . 2D-05i Pre-CTD Procedure Network# 10146793 December 15,2006 The 2D-05 CTD sidetrack will add two A-sand laterals while hopefully leaving the C-sand straddle intact. The straddle is confirmed to be leaking at the production mandrel at 7587' MS. This procedure lays out steps for securing this leak while laying in a cement kickoff plug across the A Sand. The procedure also provides for getting an A Sand static BHP survey since that information will be crucial to planning the CTD sidetrack. Note that 2D-05 has a history of scale in the tubulars. Slickline/DHD Procedure (pre-CTD): 1. PT Master & Swab valve to 4500 psi. Drawdown test on MV & SV to 0 psi. (Mastèr and swab being replaced. Expect to be finished by 12/20/06.) 2. PPOT & PPPOT-T and IC. MITIA. (Passed 11/4/06) 3. Slickline: Drift & tag PBTD. (Done 11/29/06. Tag at 7718'gKB.) RurtTTP in 2.75" D-nippfê at 7621' RKB with pressure gauges suspended underneath for A-sand SBaP. (Plug set 12/1/06, but no gauges suspended underneath.) If master or swab valves need repairlreplacement, do so while the TTP is set. 4. After 3-5 day shut-in, obtain C-sand SBHP.Run DGlV's in straddleþJ'oduction mandrels. MIT tubing and straddle to 2500 psi. (Severe leak in #8 mandrel at 7.1587' confirmed 12/1/06,) Note: The procedure from this point fo~rd assuQi.1:è$tþ~t.tþe m~ster and swab valves have been replaced, and the WRP that was set to seouretþe well ha$i~ø·þulled. The leak still exists in the #8 production mandret,.af1~(tIJ~ CA-2 plug is stiWpresent in thepnipple at 7621' RKB. The A Sand is assumed to be.significai"\tf,y\t¡igher pressure~an the C Sand, although no pressure measurement has yet been ma~on the A ~nd to confirm this. 5. Slickline - RIH with pre~~we/te~~~~f!ture gauges. R~cOrd static BHP of the C Sand. log up from the CA-2 plug at 7621' across the~~tif~\~tr~t~~~m~IX'..Jhe primary purpose of this survey is to determine if the CA-2 pl49il:tleaking and w~t1:\~r crossflOW~i"\ues into the C Sand, in addition to determining the static pressureon~ QS~nd. 6.Ptlt the well on injectio~\t() reducedíff~f~ptial on the CA-2 plug at 7621'. RIH with slickline, pull the CA-2 plUg ¡at 7621' MD, POOH. 7. MU pr8$s'u.r~ gauges to ha~.below a CA-2 plug. RIH, set CA-2 plug with gauges in D nipple at 7621'. POOH. R~ÇQfd A Sand st~c BHP for 48 hours. When it is time to pull the gauges, once again RU to pump down the tubimg.while pullimQ the CA-2 plug. Pull gauges, POOH. Pull the dummy valve from mandrel #6 at 7418' MD, leavìøø~n empty pocket. This will allow the A Sand to crossflow to the C Sand, and will also prep for the subSèqOent squeeze operation. (Note: Confirm that AOGCC has approved the 10-403 application and that partners have approved the AFC before proceeding with the remaining operations.) 8. E-line: RIH with tubing punches for 3%", 9.3 ppf tubing. Correlate with CCl, shoot tubing punches into the 8' pup joint immediately above the D-nipple at 7621' RKB. 9. Prepare to blend aM-I SafeCarb pill and bullhead down the tubing. The objective is to plug off both the A Sand and the C Sand simultaneously with the Safecarb pill. The following Safecarb pill recipe is recommended based on 750 md AlC Sand permeability. The pill has loading of 150 ppt¡ of carbonate, which is the equivalent of 1.6 bbl of carbonate for every 10 bbl of slurry. Recommended pill size = 50 bbl pumpable. . Tubing capacity (0.0087 bbl.ft) = 66.3 bbl to tubing tail at 7626' MD Page 1 of2 December 15,2006, DRAFT . . . 7" casing capacity (0.0383 bbl/ft) = 3.5 bbl (tubing tail to tag at 7718' MD) . Straddle volume, 7" x 3%" (0.0264 bbl/ft) = 6.0 bbl SafeCarb Pill Recipe Product Volume HEC polymer 2.5 ppb Dual-Flo viscosifier 3.0 ppb Safe-Carb 2 (VF) 2.0 ppb Safe-Carb 10 (F) 3.0 ppb Safe-Carb 20 U 88.0 ppb Safe-Carb 40 (M) 57.0 ppb 10. Establish injection down the tubing with seawater. BI.1 1head 50 bbl carbonate pill downthetubing, displacing with diesel (for freeze protect). Reduce pumping rate once the switch is made to diesel to encourage bridging of the carbonate. Do not exceed _psi$queezepressure or pump more than 35 bbl of diesel in the displacement. If we do not observe an increase in pressure indicating a squeeze, shut down and allow carbonate to settle out. RD pump truck. 11. Coil tubinq: RIH with wash nozzle. Clean out carbonate down to ±7600? MD, keeping backpressure high enough to prevent the A Sand from unloading th$carbonate. POOH, mail1tairtpressure overbalance. 12. Slickline - RIH, set dummy valve in open manqrel at 74t8'..,.0, POOH,RD slickline. 13. Coil tubing: RIH with Wa$~noZ4:le. Continue cle~ing out carbonate down to ±770Q' MD, keeping backpressure high enöugh tot>~~nt the A Sand from unloading the carbonate. Planned KOP for CTD is 7655' MD, so want~minimum ot~' of rathole belqW this for laying in cement. 14. Lay in 17.0 ppg cemeôti~prder.~.p.I~.g back the A-S~r'1d perfs. Place top of cement at 7100', which should leave about 4.2 bbl of ce'f'el1taböve~~J~ki!1g I11clndrel at 7587'. Total estimated cement volume = 8.1 bbl. Circ.tllateollt excess œ~!1t. PU, bégiø~lying squeeze pressure. Maximum squeeze volume = 2.2 bbl.f'or the fjrst~~~it~tion, ptJ~H\1.1 bbl as slowly as possible up to a maximum pressure of _ psi. If Rr~ssure breaks ba~pfo\shows al1~.p~her sign of pumping into the formation, stop pumping. Shut down for 1~minutes, monitoringiffl~eeze pr~~~rr' . Pump 0.6 bbl for second hesitation and 0.5 bbl for final h~jtéltion. Duration of th~\~esitationsçan be lengthened if not getting an indication that we're achieving a squ¢~e. Do not under a.nycircumstance pump away the final 2.0 bbl of cement left in the tubing. POOH displacing pipe volume only. RDMO coil tubing. 15. Slickline: Drift~ tag TOC.Pressure test cement plug to 2500 psi. 16. Coil TubinQ: PU motórand mill. Drill out cement to ±7610' MD. Pressure test plug to _ psi. 17. Prep site for Nordic 2. Page 2 of2 December 15,2006, DRAFT . . l SARAH PALIN, GOVERNOR ¡i_ 1·'--- i) U ! "~. AlASKA OIL AND GAS CONSERVATION COMlVIISSION / 333 W. 11h A VENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (901) 219-1433 FAX (901) 216-15423 Gary Eller Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 I ~~.. \. i,'"-T Re: Kuparuk River Field, Kuparuk. Oil Pool, 2D-05 Sundry Number: 306-377 ("t..if"- 1, 1i<1%~~;;¡:) W'\,;;lQ1¡!¡ \!~~... - Dear Mr. Eller: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thislVday of December, 2006 Encl. þ ~rs (2-!tZ/-b {j1} ,. ~,. fJ STATE OF ALASKA · !r, \~l ALASKA OIL AND GAS CONSERVATION COMMISSION It APPLICATION FOR SUNDRY APPROVAL AI RECEIVED DEC Q 1 2006 20 MC 25.280 aska Oil g, r,A~ PM_ r-. 0 0 0 . 0 1. Type of Request: Abandon 0 Suspend Operational Shutdown Perforate wai4l7Cho§e utn~r Alter casing 0 Repair well 0 Plug Perforations 0. Stimulate 0 Time Extension Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhìllìps Alaska, Inc. Development 0 Exploratory 0 184-126 .,/ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21157-00 .,./ 7. If perforating, 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 n No 0 2D-05 , 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25658, ALK 2584 RKB 126' Kuparuk River Field I Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7990' " 6363' 7802' Casing Length Size MD TVD Burst Collapse CONDUCTOR 116' 16" 116' 116' SUR. CASING 3697' 9-518" 3823' 3159' PROD. CASING 7845' 7" 7971' 6345' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7534'-7578',7678'-7688',7700'-7742' 5949'-5988', 6078'-6087', 6097'-6136' 3-1/2" J-55 7626' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'FHL' HYD SET PERM; BAKER 'FB-1' pkr= 7379'; 7606' Baker 'FVL' SSSV @ 1870' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 . 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: December 15, 2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission"iepresentative: \ 18_ I he"by,~fo"'OI"" -"e aod "'''''ct '0 'he be" of my knowledge Contact: Gary Eller @ 263-4172 Printed Name Garv Eller_ ~ Title: Well:~::uP ~\g\;~I\)~ Signature ,~\. ~ \... ~ Phone 263-4172 ~ " Commission Use Only . -"---J sun~D7£r~ 31 r-¡ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: E \.\ V'o4. ~\\ <..o"\'Û \ ~'\.\,)\~'M.<L~\- \(L'- àG~;~·,S:..d;, ;)1f'l, ,<:..0-\\ 'QQ..,'dJ~..dfš'Ç. ~-OO \""\ Mo., "-.\ ""-> h '? \e.S"". .- -- . - ., S'b....'e"tFo"" Re""'d. u.c:f\ ~ ~ RaoMS SF, J .1 2D06 ~~Wc APPROVED BY Date: IZ.,/t ~6 Approved by: T '/1 COMMISSIONER THE COMMISSION Form 1 0-403 Revisede1~ I C; I'M N¿' ~ Submit in Duplicate A IZ. .¡(.~ ~/~¿ . . 20-05 Procedure cro "A" Sand Lateral Preparation ,/ 1. E-line: (Note: Confirm that AOGCC has approved the 10-403 and partners have approved the AFC before proceeding with this operation.) RIH with tubing punches for 3%", 9.3 ppf tubing. Correlate with CCl, shoot tubing punches into the 8' pup joint immediately above the D-nipple at 7621' RKB. 2. Coil tubina: (Note: Confirm that AOGCC has approved the 10-403 and partners have approved the AFC before proceeding with this operation.) RIH to depth of PBTD previously determined by slickline. lay in 17.0 ppg cement in order to plug back the A- ,/ sand perfs. Place top of cement up around 3%" tubing tail to 7613' MD. Circulate out excess cement, POOH. RDMO coil tubing. 3. Slickline: Drift & tag TOC. Pressure test cement plug to 2500 psi. (Note: Open C Sand "' perfs above top of cement. No need for AOGCC witness of the pressure test on the cement plug.) 12/1/06 . . ConocoPhillips Alaska,lnc. KRU 2D-05 ii 'i:i/'?i···:i:i.i..i···': . i')i) Yi ·····iii ·)iZiii,):..i··.·.··.i·) )i API: 500292115700 Well Tvpe: INJ AnQle (ã) TS: 28 deQ (éV 7532 ·i SSSV Type: TRDP Orig 9/20/1984 Angle @ TO: 23 deg @ 7990 sssv Completion: (1870-1871, Annular Fluid: Last WIO: Rev Reason: C/O CVs 00:3,500) Reference LOQ: Ref LOQ Date: Last Update: 10127/2005 Last TaQ: 7802 CTMD TD: 7990 ftKB Last TaQ Date: 8nt20œ Max Hole AnQle: 47d.3700 Descriotion Size Too Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 116 116 62.50 H-40 SUR. CASING 9.625 0 3823 3159 36.00 J-55 PROD. CASING 7.000 0 7971 6345 26.00 J-55 Size I TOD Bottom TVD Wt I Grade , Thread 3.500 I 0 7626 6031 ill' J-55 EUE 8RD Interval TVD Zone Status Ft SPF Date TVDe Comment 7534 - 7578 5949 - 5988 C-4,UNIT 44 12 9/28/1984 IPERF Dresser Atlas B 7678 - 7688 6078 - 6087 A-5 10 4 9/28/1984 IPERF Dresser Atlas 7700-7742 6097-6136 A-4 42 4 9/28/1984 ¡PERF Dresser Atlas St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2074 1907 MMH FMHO DMY 1.0 BK-2 0.000 0 9/28/1991 2 4210 3427 MMH FMHO DMY 1.0 BK-2 0.000 0 9/28/1991 3 5722 4526 MMH FMHO DMY 1.0 BK-2 0.000 0 9/28/1991 4 6842 5376 MMH FMHO DMY 1.0 BK-2 0.000 0 9/28/1991 5 7319 5762 Otis HP Round DMY 1.5 RO 0.000 0 10/211989 iX i.)ci' PBR St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv (7366-7367. Mfr Run Cmnt OD:35OO) 6 7418 5847 MMH MMH FMHO HFCV 1.0 BK 0.188 0 10/22/2005 Open 7 7485 5906 MMH MMH FMHO HFCV 1.0 BTM 0.188 0 10/22/2005 Open 8 7587 5996 MMH MMH FMHO DMY 1.0 0.000 0 0/1412004 111 PKR 1. LA TCH BROKEN OFF WHEN A TTEMPT MADE TO PULL DMY 4/7/2001 (7379-7380, OD:6.151) DeDth TVD Tvpe Descriotion ID 1870 1751 SSSV Baker'FVL' (Locked Out 7/26/94) 2.810 7366 5802 PBR Baker 10 3.000 Injection 7379 5813 PKR Baker 'FHL' hvd set PERM 3.000 MandlelNalve 6 7606 6013 PKR Baker 'FB-1' 4.000 (7418-7419. 7621 6027 NIP Camco 'D' NiDDle NO GO 2.750 7625 6030 SOS Baker 2.992 Injection 7626 6031 TTL 2.992 MandlelNalve 7 (7485-7486, - - - - - - - - - - I Injection MandrelNal,,: (7587-7588, PKR (7606-7607. 00:6,151) NIP - .- - 1- - Qu;)~~ \0"- 'ì~d' (7621-7622. 00:3.500) ,OC- -\x:,\\O.M-.~ 4.. <0' ~ \. \~ I TUBING (0-7626, ~(K ~~~ - ~ ~\\) 5.~ b~\~ OD:3,500. ID:2.992) Perf - - ~/1"'\"O 'k ~ (7678-7688) - - !J~l~/6-a~ - - = = Perf - - (?lOtH742) ( - - ~~\\) V<.:\. ( C. \, ("r-.\\r.~ "1)Ç~D" . . Review of Sundry Applications 306-377 ConocoPhillips Alaska, Inc. Well Kuparuk 2D-OS Kuparuk River Field, Kuparuk River Oil Pool AOGCC Permit 184-126 Requested Action: ConocoPhillips Alaska, Inc. (CP AI) proposes to abandon existing perforations in this wellbore so the well can be sidetracked to more effectively develop the pool. Recommendation: I recommend approval of CPA!' s proposed action. Discussion: CPAI proposes to plug the existing 'A sand' perforations in the subject well so that they can do CTD a lateral sidetrack into the same sands, the existing 'C sand' perforations will not be affected by the proposed operations. The well was completed as an oil producer in October 1984, but has been a WAG injector since November 1985. It is not specified in this application but it is assumed that the lateral will also be an injector since the area around the wellbore should be well swept after 21 years of injection. The new wellbore configuration should improve development of the 'A sand' in this pool. Conclusion: Sidetracking this well into a lateral injector should improve current operations in this portion of the pool. Therefore, it is prudent to authorize CP AI to perfonn their requested plugging activ~~,cause of the future benefit that will be achieved. D.S. RObyd·~~ Reservoir ~~ ,. December 11, 2006 RE: 2D-05 Plug A sand perfs . . Tom - Thanks for looking into 2D-05. 1) The choice of 12/15 was a guess. No problem at all with issuing the sundry on Monday. 2 & 3) I'm still working out some of the details. In particular, the leaking production mandrel at 7587' MD is causing problems - will meet today to better decide how to deal with it. I'll keep you posted on our plans. It is possible that we may have to plug off the C Sand perfs with carbonate or cement. If we decide to go that way, I'll send another 10-403 to you for that work. I know that's not all that you were looking for, but I'll get back to you when I havè more complete answers. -Gary Eller -----Original Message----- From: Thomas Maunder [mailto:t:om maunder@admin.state.ak.us] Sent: Wednesday, December 06, 2006 10:56 AM To: Eller, J Gary Subject: 2D-05 Plug A sand perfs Gary, I am looking at your proposal and have a couple of questions. 1. How firm is the start date of 12/15? If this issues on Monday will that meet your schedule? 2. While I was able to assess what you plan, a little more detail would be appreciated. In particular, the planned cement yields/volumes should be included. 3. How will you accomplish the pressure test with the C sand open above the top of cement? Thanks in advance for your reply. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 12/11/20063:56 PM Schlumberger NO. 3492 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Anchorage, AK 99503-2838 A TTN: Beth 5CA\'!NED NO\1 (1 2 2005 Field: Well Job# Log Description Date BL 3M-07 11015737 INJECTION PROFILE 09/26/05 1 1 E-18 11015745 GLS SURVEY 10/02/05 1 1 Q-22 11015744 PRODUCTION PROFILE 10/01/05 1 1 G-08A 11072911 PRODUCTION PROFILE 10/01/05 1 1G-10A 11072910 PRODUCTION PROFILE 09/30/05 1 2C-04 11072907 INJECTION PROFILE 09/27/05 1 ..20-05 11072909 INJECTION PROFILE 09/29/05 1 2P-429 11056695 INJECTION PROFILE 09/18/05 1 2N-306 11056696 INJECTION PROFILE 09/19/05 1 1 D-122 11015730 INJECTION PROFILE 09/06/05 1 1 C-111 11015732 INJECTION PROFILE 09/22105 1 1 D-114 11015728 INJECTION PROFILE 09/04/05 1 2V -08A 11072913 INJECTION PROFILE 10/03/05 1 3M-01 (REDO) 11015736 INJECTION PROFILE 09/25/05 1 31-04 10092325 PRODUCTION PROFILE 10/02105 1 1 E-1 05 11015726 TEMPERATURE SURVEY 09/02/05 1 SIGNED: :lLtl (JjjJ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 10/07/05 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk -/ Color CD --- /7 G~ÁA'1-r ¡X If -( /vc,,< Ç¡L~ MEMORANDUM TO: Jim Regg ~.. I J7c J "4 P.I. Supervisor 'Kt1li Ie( . l ( FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RJV UNIT 2D-05 Insp Num: mnCS040619191756 Rellnsp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday. June 23. 20Q.t SllBJECT: t-.techanicallmegflt)' Tests CONOCOPHTLLlPS ALASKA INC ~ D-(15 KUPARUK. RIV UNlT ::!D-OS Src: Inspector NON-CONFIDENTIAL Reviewed B,,: . ~.-.. P.I. Supn' :Jtt:-- Comm API Well Number: 50-029-21157-00-00 Permit Number: 184-126-0 Inspector Name: Chuck Scheve Inspection Date: 61\9/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ::!D-05 Type Inj. G TVD 6361 IA 1J::!5 ::!310 2180 2280 P.T. 1841260 [T)'peTest SPT Test psi 14S3.::!5 OA 150 150 150 150 Interval ..¡ '\'R TST PIF P Tubing 3300 3300 3300 DOO Notes: Pretest pressures observed for 30+ minutes and found sLab1e. Well demonSlrated good mechanical inlegrity. Wednesday. June 23, 200-1 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: THRU: Julie Heusser, ;~t,~\'~ Commissioner TOm Maunder, . P. I Supervisor Chuck'Scheve; Petroleurr Inspector sUBJECT: FROM: January 28, 2001 Safety Valve Tests Kuparuk River Unit ~2D &2E Pads SundaY, January 28, 2001' I traveled` t© the Kuparuk River Field and witnessed the Semi annual safety valve system testing on 2D & 2E Pads. As the attached AOGCCi'$afety Valve SyStem Test Report indicates I Witnessed the testing of 9 Wells and 18 componentS with one failure on 2D Pad and 5 wells and 10 components with one failure on2E Pad, The SurfaCe Safety Valve on Well 2E-16 had a slow leak when pressure tested, This valve will be serviced and retested by the Operator. The.SUrface 'Safety Valve On well 2D-05, a WAG injector, could not be tested due to a leaking wing valve. This valve will be tested as soon as the wing valve is repaired. . Earnie Barndt conducted the testing tOday he demonstrated good test procedure and was a pleasure to-WOrk with AlI the wellhouses entered at these lOcations were clean and all related equipment appeared to be in good condition. - .SummarY: I witnessed the semi annUal SVS testing at 2D & 2E Pads in ·the Kuparuk River Field I failure 5.56% failure rate 1 failure 10% failure rate KRU 2D Pad, 9 wells,. 18 components, KRU 2E Pad, 5 wells, 10 comPonents, 24 wellhouse inspections - Attachment: SVS KRU 2D & 2E pads 1-28-01 CS X Unclassified Confidential (UnclaSsified if doc. Removed) SVS KRU 2D & 2E Pads 1-28-0I CS.doc Alaska Oil and Gas Conservation COmmission Safety Valve System Test Report Operator: Prillips Operator Rep: Eamie Bamdt AOGCC' Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 2D Pad Separator psi: LPS 99 HPS 1/28/01 I . Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GI~J, Number Number PSI PSI ,Trip Code Code Code Passed GAS or CYCLE, 2D-01 1841710 '99 -70 65 P P OIL i 2D-02 1841520 2D-03 1841530 2D-05 ~(. ':1841260 ' 3750 2000 1750 P. 7 WAG 2D-06B 1981760i 99 ' 70 55 P P OIL 2D-07 1841430 , 3750 2000 ..1850 . ,p P .., WAG 2D-08 18412701 99 70 60 P P OIL 2D'09 1841030 99 - 70 55 P P OIL 2D-10 1841010 -, 2D-11 1840990 2D-12 1840940 99] 70' - 60 p p ' OiL 2D-13 1840120 99~ 70 ., 60- P P ' OIL 2D-14 1841590 2D- 15 184'1600 99 70 ' 60 'p P ' OIL , . , 2D-16 1841610 , , Wells: 9 Components: 18 Failures: 1 Failure Rate: 5.56% 12390 Day Remarks: Surface safety, on 2D-05 not tested due a slow leakin8 wing, valve Grove valve could be closed due to snow drifts. RJF 1/16/01 Page 1 ofl SVS KRU 2D Pad 1-28-01 CS.xls Alaska Oil and Gas COnservation Commission Safety Valve System Test Report Operator: phillips Submitted By: Chuck Scheve Operator REP:' Eamie Brandt AOGCC.Rep: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 2E Pad Separator psi: LPS 99 HPS 1/28/01 , · i Well Permit Separ Set L/P Test Test Test Date on, WAC, Cra J, Numbe, r Number psi Ps, l ~ TriP'- Code Code Code Passed GAS or CYCLE 2F~-07 1931040 . 2E-08 1931890' 991 70 .60 ' P 'P . . , ' ;2E-09 1842400 . ~ , , 2E-10 1842300 . 99 70 60' P P . 2E-11 1842260 99 70 50:- P .P 2E-15, ' 184.1890 , 99 70 50' . P e , . . 2E'16 1841900 99 70: 50 P 4 i ,, . : , , Wells: 5 i Components: 10 Failures: 1 Failure Rate: 10.00o/~190 my - Remarks: Surface ~fety on 2E21'6 had SloTM leak when pressure tested. Valve will be Serv~ced ,a, . retested by operator. RJF 1/16/01 Page 1 of 1 SVS KRU 2E Pad 1-28-01 CS.xis STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation shutdown Pull tubing Alter casing Stimulate Plugging .. Repair well Perforate Other X 2. Name of Operator Alaska 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X Location of well at surface 168'FSL, 550' FEL, Sec. 23, T11N, R9E, UM At top .of productive interval 1351' FNL, 1365', FWL, Sec. 24, -I'11N, R9E, UM At effective depth 1207' FNL, 1420' FWL, Sec. 24, T11N, R9E, UM At total depth 1171' FNL, 1434' FWL, Sec. 24, T11N, R9E, UM 6. Datum elevation (DF or KB) RKB 126 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-05 9. Permit number/approval number 84-126/94-210 10. APl number 50-029-21157 11. Field/Pool Kuparuk River Oil Pool 12. Present-well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 7990 6361 7895 6274 feet feet feet feet Plugs (measured) None Junk (measured) None feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 116' 16" 3801' 9.625" 7934' 7" measured 7534'-7578', true vertical 5948'-5987', Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 @ 7626' Packers and SSSV (type and measured depth) Cemented 224 SX CS II 1075 SX AS III & 685 Class G 625 SX Class G 7678'-7688', 6076'-6085', 7700'-7742' 6096'-6134' Measured depth 121' 3840' 7971 ' True vertical depth 121' 3170' 6344' RE([EIVED SEP -9 1994 Ataska Oil & Gas Cons. Commission Anchorage PKR: Baker FH @ 7379' & Baker FB.@ 7606'; SSSV: Baker FVL @ 1870' (locked out)-OTIS MCX Ini Valve @ 1855' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure Run MCX Iniection Valve 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or In!ection Data · OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 7 7 3 0 2750 7 9 0 0 2750 Tubing Pressure 3895 3876 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector _X (WAG Iniector) Oil _ Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Form 10-404 Rev 06/15/88 Wells Superintendent Date ~.~~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. WELL 2D-05 DA~ ~-' 7/26/94 ~ME 1130 1200 DESCRIPTION OF WORK - Lock out SSSV/Run MCX Inj Valve CONYRACTOR I KEY PERSON HES-Kevin C0rcoran Unit~70175 ,OP~.RATON AT REPORT TIME_ ~ F~i COMPLETE. -"J INCOMPLETE. FIELD EST: · $4,101 LOG ENTRY srI'P: 3850# 7"CP: 3000# 9-5/8'CP: 400# KUPARUK'RIVER UNIT WELL SERVICE'REPORT IAFClCC# . SCA# 230DS28DL/40115 ACCUMULATED COST -_.._ · $4,101 ......... Paeje I of 2 MIRU I-lES & Lil Red-PT LUB to 4500g-O~ Displaced well wi20 bbls 125' diesel & RIH w/BAKF~R LOT-Set @ 1857' WLM-(SITP 3200g)'P~ss up tubing to 4500fl-no indication of sleeve shifting-increase press to 4750#-no indication of sleeve shifting- Bleed TP to 3200~-Press up tubing to 4800#-no indication sleeve shifted ~ ' ' 1300 'Ring blew ~i below stuffing box-POOH w/tools while bleeding lub to bleed tank-No spillF'~ RD Lubricant ~0- change all o'rings ............. - ..... RU Lab-pT to 5~K RIH w/Baker LOT-Set @ 1857' WLM-Press robing to 4600g-No indication of sleeve shifting BOP s~d l~g from ar°und r~'n-Stem-POOH , . , Br°ke'BOP d0-~,n mid ~ebuilt same 1400 1415 . 1445 . _ _ 1500 1615 1630' 1645 PT BOI~'~:-I~i~ t° 50O0#-OK! Displac~ ~/ell:~t/60 bbls dieSel ........................... RIH w13.5" wire brush-Ran through !i!ISV'~//bi'fis--hTE-ufiitblEt6 rag-fl~.~per-bled csg press-t09~--- press h-~ldiiig-@-2200#-TP 2200#-indicates SSSV locked open ......................... '1~'I-I w/3"'Gs w/M-I probe & M-1 lock w/MCX Inj valve (#347 - 1.092 bean)-Set @ 1855' 1730 1830 RDMO WLM-POOH (pUmped 30 bbls dieSel while setting MCX5 SITP 2200g-Bled TP to 600g-Held Good-C. nmd cloSure teat ! ~ked out SSSV~Sei-~iCX Inj V/d~t~2-G6~l Cl~s~ Tgst w/l'6(K~ DP' ! _.-.2. ...... l~'mal SITP: ~22~X)ff 7"CP:90(~ 9-5/8"CP: 300~ [CHECK THIS BLOCK' IFSUMMARY IS CONTINUED ON BACK -4'I.~,'~ :; - -_. ,c,__' .: ' AI:i3B-7031 · t'ChillFactor i · ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 28, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action 2D-05 Variance (Inj Val~e) If you have any questions, please call me at 263-4806. Sincerely, M. E. Beck Engineering TeChnician Kuparuk/CPF-2 Production Attachments FTR072895 (w/o atch) ~U6 "'~ 't994 Gas Cons. C0mmissiort Anchora0~a ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casing __ Repair well Change approved program Operation Shutdown m Re-enter suspended well __ _ Plugging_ Time extension _ Stimulate__ Pull tubing __ Variance ~ Perforate __ Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 168' FSL, 550' FEL, Sec. 23, T11N, R9E, UM At top of productive interval 1351' FSL, 1365' FEL, Sec. 24, T11N, R9E, UM At effective depth 113~' FSL, -/~' FVVL, Sec. 24, T11N, R9E, UM At total depth 1171' FSL, 1434' FWL, Sec. 24, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 799O 6361 feet feet 6. Datum elevation (DF or KB) RKB 126 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-05 9. Permit number 84-126 feet 10. APl number 50-029-21 157 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 7 8 9 5 true vertical 6274 feet feet Junk (measured) None Casing Length Structural Conductor 1 1 6' Surface 3 8 0 1 ' Intermediate Production 7 9 3 4' Liner Perforation depth: measured 7534'-7578', true vertical 5948'-5987', Size 16" 9 -5/8" 7" Cemented Measured depth True vertical depth 224 Sx CS II 121' 121' 1075 Sx AS III & 3840' 31 70' 685 Sx Class G 625 Sx Class G 7971' 6344' 7678'-7688', 6076'-6085', Tubing (size, grade, and measured depth) 3.5", 9.3 #/ft., J-55, w/ tail @ 7626' Packers and SSSV (type and measured depth) 7700'-7742' 6096'-6134' RECEIVED AUG - 1 1994 Alaska 0il & Gas Cons. Commission Anchorage Pkrs: Baker 'FH' @ 7379'~ Baker 'FB' @ 7606'; SSSV: Baker 'FVL' @ 1870' 13. Attachments Description summary of proposal ~ Detailed operation program _ Lockout SSSV and install sub-surface, spring controlled safer7 valve. 14. Estimated date for c°mmencing operation 15. Status of well classification as: July 1994 Oil m Gas 16. If proposal was verbally approved 7/26/94 Name of approver Blair Wonzell Date approved Service BOP sketch Suspended __ WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~~ Title Drillsite Supervisor Conditio~Cs of approval: Notify Commission so representative may witness Date ?/.Z..~'/~ IApproval Np. Plug integrity __ BOP Test Mechanical Integrity Test_ Location clearance Subsequent form require 10- ~O~ Approved by order of the Commission Original Signed By David W. Johnston Commissioner Form 10-403 Rev 06/15/88 ^pproved Copy Returned .,. SUBMIT IN' TRIPLICATE Attachment to Application for Sundry Kuparuk Well 2D-05 July 26, 1994 Subject well was converted to gas injection on July 3, 1994. Although the subsurface safety valve flapper appeared to close adequately when tested, there were problems in keeping the control line to the valve fully pressurized. Testing suggested that the control line leaked somewhere below the wellhead. A variance is being sought to lockout the surface-controlled subsurface safety valve. An independent, spring-action injection valve will be Set in the subsurface safety valve profile to provide downhole well control. Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: June 17, 1988 Transmittal #: 7194 RETURN TO: Transmitted herewith are the following items. one signed copy of this transmittal. 1L-16 20-05 2A-06 2W-09 3K-02 2G-07 2G-07 3B-06 3Q-15 ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510.0360 Please acknowledge receipt and return Kuparuk Well Pressure'Report Water Injection Spinner Data Sheet Water Injection Spinner Data Sheet Gas Injection Spinner Data Sheet Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report ~ - 6-02-88 PBU - Sand A 6-08-88 Both Sands 6-09-88 Both Sands .6-08-88 Both Sands 6-10-88 Tubing 6-10-88 Tubing 6~14-88 Casting 6-06-88 Static - Sand A 5-15-88 PBU - Both Sands Alaska Ott& Gas Cons. Commission knowledged' A~~ .................... Date' _DISTRIBUTION: D & M --~ State of Alaska _ .. Chovl'Oll - Mobil Unocal SAPC ATTACItMENT 1 PAGE 1 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE q - INJECTIVITY PROFILES FIRST QUARTER 1987 SUBMITTAL WELL NUMBER '>~'~2C-03 ~2c-o~ ,,/'" 2 D-05 "'~2W-05 ~ 2w-o8 '>~ 2X-02 "~.2x-o3 ~"-'2X-06 ~ 3F-Oq ~'~ 3F-O? APl DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING 50-029 INJECTION SURVEY SURVEY ~URVEY WATER 20968 20973 21157 21208 21228 20982 20987 20988 21qq9 21q63 12/12/85 02/03/87 SPINNER FOLLOWUP A&C S 11/09/85 02/01/87 SPINNER FOLLOWUP A&C S 11/09/85 02/0h/87 SPINNER FOLLOWUP A&C SS 11/22/85 03/05/87 SPINNER FOLLOWUP A&C SS 11/15/85 03/06/87 SPINNER FOLLOWUP A&C SS 11/19/85 02/07/887 SPINNER, FOLLOWUP A&C SS 11/0b/85 03/02/87 SPINNER FOLLONUP A&C SS 11/0~/85 03/0q/87 SPINNER FOLLO~UP A&C SS 05/04/86 02/08/87 SPINNER INITIAL A&C SS 05/06/86 02/09/87 SPINNER INITIAL A&C SS A&C A&C A&C A&C A&C A&C A&C A&C A&C A&C I NJ ECT I ON BWPD · Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1987 Mr. C. V. Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Subject- Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1987. The data is provided in the form of spinner logs or separate zone surveys as listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have anx questions concerning the information reported, please contact me at (907) 263-4262. Sincerely, Operations Engineer BBB/SPT: pg: 0069 Attachments v;AYO Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Bc )0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 9, 1985' Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: Well Action Date Performed 1B1 Frac 11 /6/85 1E8 Frac 1 2 / 6 / 85 1E-1 9 Convers ion 1 0/1 7/85 1E-21 Conversion 8/1/85 1E-23 Convers i on 1 0 / 23 / 85 1G-2 Frac 12/6/85 1R1 Frac 11/5/85 1R2 Frac 11 / 5 / 85 1R4 Frac 11/6/85 1R6 Frac 11/6/85 1R1 3 Frac 11/1/85 1R1 4 Frac 11 / 1 / 85 2D-5 Ac id i zed 6/1 8/85 2D-6 Ac id i zed 6/18/85 2V5 Conver s i on 7 / 6 / 85 on the If you have any questions, please T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) call me at 263-4212. RECEIVED ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ~' ALASKA O~L AND GAS CONSERVATION CON, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. NaA~e~12ASKA, i NC:. 3. Ad?e, ss O. BOX 1 00360, ANCHORAGE, ALASKA 9951 0 4. Lo~~ LOCATION- 168 ' FSL, 550 ' FEL, T11N, R9E, UM SEC. 7. Permit No. 84-126 8. APl Number 50- 029-21157 9. Unit or Lease Name 23, KUPARUK RIVER UNIT 10. Well Number 2D-5 11. Field and Pool KUPARUK RIVER FI ELD I 6. Lease Designation and Serial No. KUPARUK R I VER O ! L ADL 25658 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or ComPleted Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On June 18, 1985, the "C" sands of Kuparuk well 2D-5 were acidized improve production. The treatment consisted of 57 bbls of diesel, bbls of 12% HCL and 46.6 MSCF of nitrogen. Diesel was used for flushing and nitrogen to aid well cleanup. Prior to starting job, equipment was pressure tested to 5000 psi. to 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _.~,/-~.<.~ ~~ Title KUPARUK The space below for Commission use OPERAT IONS COORD I NATOR Date~2/6!85 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1430 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~ Post Office. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 1985 Mr. C. V. Chatter Alaska Oil and Ga 3001 Porcupine Dr Anchorage, AK 9 ton, Chairman s Conservation Commission ive 9501 Dear Mr. Chatterton. Attached in duplicate are subsequent notices following wells at the Kuparuk River Field' Wel i Action Date Performed on the 1F-4 1F-5 1F-8 1G-3 1G-4 1L-3 1L-5 1Q-8 1Q-12 1Q-14 1R-3 1R-10 1Y-7 1Y-10 1Y-15 1Y-13 2B-6 2B-8 2B-11 2B-12 2C-2 2C-4 2C-5 2C-7 2D-4 2D-5 ' 2F-3 2F-4 2F-15 2F-16 2D-10 2D-16 Conve Conve Conve Conve Conve Conve Conve Conve Conve Conve Conve Conve Conve Conve Conver Conver Conver Conver Conver Conver Conver Conver Conver Conve Conve Conve Conve Conve Conve Conve Conve Conve rs on rs on rs on rs on rs on rs on · rs on rs on rs on · rs on o rs on · rs on rs on · rs on s on · s on · s on s on s on · s on s on · $ on · s on rs on · rs on · rs on · rs on · rs on rsion rsion rsion rsion 10/24/85 10/24/85 10/24/85 10/25/85 10/25/85 10/24/85 10/24/85 10/25/85 10/25/85 10/25/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 11/5/85 11/5/85 11/5/85 1115185 11/6/85 11/6/85 11/6/85 11/6/85 11/6/85 1116185 11/2/85 11/2/85 11/2/85 11/2/85 11/6/85 11/6/85 . ~= ._._ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO~nMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~' OTHER [] 2. Na~,,o68pe,,~J..~SKA, INC. 3'Ad~re. SS o. BOX 100360, ANCHORAGE, ALASKA 9951 0 4. Location of Well SURFACE LOCATION' 168' FSL, 550' FEL, T11N, RgE, UM SEC. 23, 7. Permit No. 8q-126 8. APl Number 50- 029-:21157 9. Unit or Lease Name KUPARUK RIVER UNIT 5. Elevation in feet (indicate KB, DF, etc.) 126 ' (RKB) 12. I 6 . Lease Designation and Serial No. ADL 25658 10. Well Number 2D-5 11. Field and Pool KUPARUK RIVER F! ELD KUPARUK RIVER O I L POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate} (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 6 1985 Kuparuk well 2D-5 was converted from a producer to a water iniector well as part of the full field waterflood conversion effort. Water is being injected into both the "A" and "C" sands. RECEIVED Alaska Oil & Gas Cons. 6om~f:ission Anchora. d'~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: Title KU PARU K Date OPERATi ON,S COORD i NATOR 11/15/85 Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ~ .100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 sePtember 2'0, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501~ Dear L C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterfloOd of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. .As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, · T M. Drumm Kuparuk Operations Coordinator cc- J.F. Beall TMD:ps:013 RECEIVED s E P o O~ & G~s Co~s. Comrnissio~ AnChorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK/~,'"'-'"L AND GAS CONSERVATION Cr'"-'!MISSION SUNDRY OTICES-AND REPORT,.% ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. see attached 99510 OTHER [] 3. Address P.O. Box 100360, Anchorage, Alaska 4. Location of Well N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. I 6 . Lease Designation and Serial No. see attached 8. APl Number 5o- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list of~^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion:' to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. sE? 2 o 19".,5 Aiasl<a Oil & Gas Cons. Com, rn~ssion Anchorage 14. t hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,_~, ~'~.-~ ~~rJ~'~-~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 Approved Co~y ... By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate _ 6. - 7 - 8 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK:009 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 -. 156 159 172 177 84-118 139 80 85 106 128 132 85- 6 7 20 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974 029-21177 21176 21157 21169 21135 21134 21183 21185 25653 25658 2580 12 10 12 /15/85 /15/85 /15/85 2579 2584 12/15/85 10/15/85 10/15/85 12/15/85 10/15/85 12/15/85 12/15/85 10/15/85 029-21246 25658 2584 12/15/85 21227 " " 12/15/85 21213 " " 12/15/85 21214 " " 12/15/85 029-21058 25657 2583 12/15/85 21063 " " 12/15/85 21062 " " 10/15/85 21065 " " 10/15/85 21032 " " 12/15/85 21035 " " 12/15/85 21048 " " 10/15/85 21052 " " 10/15/85 029-21150 25656 2582 12/15/85 21165 " " 10/15/85 21119 " " 10/15/85 21124 " " 12/15/85 21140 " " 10/15/85 21159 " " 12/15/85 21163 " " 10/15/85 25644 2575 10/15/85 " " 12/15/85 " " 10/15/85 25643 2574 10/15/85 " " 10/15/85 " " 12/15/85 029-21269 21270 21283 21303 21262 21264 029-21037 25655 2581 10/15/85 21041 25644 2575 10/15/85 21051 " " 10/15/85 21054 " " 12/15/85 21055 25655 2581 10/15/85 21061 " " 12/15/85 25642 2573 10/15/85 " " 12/15/85 " " 12/15/85 ,, ,' ~/15/85 " k E IV 029-21279 21275 21208 21228 21235 RETURN TO: ARCO Alaska, Inc. Post Office B~,...100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 PAGE ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 'AKCHORAGE, AK 99510 DATE:06-1~ '85 TRANSMITTAL NO: 5230 2 OF 2 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. *-**CONTINUED. FROM PREVIOUS PAGE*** ~D-~5~i~I-'~ FLOWING BHP ETC 05-06-85 CAMCO 2D-3 ACID JOB PREP 05-0 7-85 BAKER 2D-3 ACIDIZE 'C'SD 05-11-85 DOWELL 2E-9 G.R. SBHP 06-11-85 OTIS 2E-13 SBHP 06-10-85 OTIS 2E-14 SBHP 06-10-85 OTIS 2E-15 SBHP 06-09-85 OTiS 2G-i FLOWING BHP 04-29-85 CAMCO 2H-1 BHP&TCL 05-27-85 OTIS 2H-15 SBHP & ETCo 04-29-85 OTIS 2H-1 BHP & ETC. 05-23-85 CAMCO 2H-3 BHP & ETC. 05-23-85 OTIS 2H-4 COMP BHP 05-23-85 OTIS 2H-14 INT. SBHP&ETC 04-28-85 OTIS 2U-5 SBHP 05-02-85 CAMCO 2U-6 SBHP & TCL 05-0 3-85 CAMCO 2U-7 SBHP PRE PROD 05-04-85 CAMCO 2U-8 SBHP & ETC. 05-04-85 BAKER/cAMco 2U-'9 PRESSURE TEST 05-27-85 OTIS 2U-!0 BHP SAMPLE 06-05-85 OTIS 2U-16 'A'SD FLUID ID 06-09-85 OTIS 2U-16 PBU 06-07-85 OTIS 2V-10 BHP & ETC. 05-17-85 OTIS 2V-11 · STATIC 05-12-85 OTIS 2V-ll STATIC 05-23-85 OTIS 2W-13 'C'SD ACID STIM 05-20-85 DOWELL 2X-12 'C'SD ACID JOB 05-12-85 DOWELL 2Z-2 E/LINE FLUID ID 05-03-85 OTIS/CAMCO RECEIPT ACKNOWLEDGED: B PAE * B. CURRIER CHEVRON* D & M DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON MOBIL* PHILLIPS OIL* NSK CLERK J. RATHMELL DATE: STATE OF ALASKA SOHIO* UNION* K.TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary of AtianticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 31, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK ~ 99501 Dear Mr. Chatterton- Attached are our notices of intention to fracture Kuparuk field wells 2D-5, 2D-6, 2D-7, and 2D-8. If you have any questions, please call me at 263-4543. uparuk Operations Coordinator / kmc Attachment (In Triplicate) RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-126 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21157 OTHER 4. Location of Well SURFACE LOCAT ION- T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 126 ' (RKB) 168' FSL, 550' FEL, SEC. 23, 6. Lease Designation and Serial No. ADL 25658 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2D-5 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "C" sand in Kuparuk well 2D-5 be acidized to improve production. The treatment will consist of 12% HCL. The acid is nitrogen to be pressure to be pumped by coil tubing unit and displaced with aid well cleanup. Prior to starting work, equipment will tested to 4,000 psi. Fluid Requirements. 12% HCL 52 BBLS Diesel 57 BBLS ANTICIPATED START DATE' JUNE 4, 1985 RECEIVED Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use ~' Conditions of Approval, if any: ltRIGIIItAL BY LONI~IE C. SMITi'I 5/31/85 Tim OPERATIONS COORDINATOR Date Approved by COMMISSIONER Approved Copy Returned · . By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ADDENDUM WELL: 9/21/84 1/26/85 1/31/85 2/O2/85 2/3/85 2~4~85 2D-5 7889' PBTD RU Schl, RIH w/CBL/6.00" gage ring, tag btm @ 7889', log up; bond good. Est'd cmt top @ 6340'. Rn GCT log. Rn pre-frac breakdn tsts in 4 stages w/total of 139 bbls gelled diesel. Prep location f/frac. RU to frac. Frac well w/total of 320 bbls gelled diesel w/2016# 100 mesh & 14,238#-of 20/40 in 7 stages. Rn Temp log f/7800'-7200'. Tag fill @ 7855'. Dril~ntendent , ARCO Alaska, Inc. Post Office B~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Revised Well Completion Reports Dear Mr. Chatterton- Enclosed are revised Well Completion Reports for the following wells' 2A-2 2D-5 2E-14 2A-3 2D-14 2E-]6 2A-4 2E-10 2G-14 2A-5 2E-11 2H-3 2C-15 2E-12 2W-11 2C-16 2E-13 2X-15 These reports were revised to reflect the cement quantity used when each well was Arctic Packed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L06 Enclosures RECEIVED APR 2 2 198,5 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany " ' ?--~ STATE OF ALASKA T · 'I ~ ALASKA '.---C AND. GAS CONSERVATION Cq ...'.11SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV I S I ON OIL ~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. ' 84-126 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21157 4. Location of well at surface 9. Unit or'Lease Name . 168' FSL, 550' FEL, Sec.23, T11N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1351' FNL, 1365' FWL, Sec.24, TllN, RgE, UN 2D-5 At Total Depth 11. Field and Pool 1171' FNL, 1434' FWL, Sec.24, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River 0il Pool 126' RKBI ADL 25658 ALK 2584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 09/09/84 09/17/84 09/28/84 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7990'MD,6361 'TVD 7895'MD,6274'TVD YES E~X NO []I 1870 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D I L/FDC/CNL/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 116' 24" 224 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3823' 12-1/4" 1075 sx AS III & 685 s;~ Class G 7" 26.0# J-55 Surf 7971' 8-1/2" 625 sx Class G & 200 s:~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7742' - 7722' 3-1/2" 7626' 7379' & 7722' - 7702' w/4 spf 7702' - 7700' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7688' - 7678' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 7578' - 7534' w/12 spf 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO ~TEST PERIOD I~ I Flow Tubing Casing Pressure !CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 124-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED Alasi~a 0ii & Gas Cons. C0f~mtssion Form 10~407 JMM2/WC08 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate .... .; ,, ::-. ~ ...... :,.-~ ~ -_.-'_-. ,~ .. ~;FO'RI~i~,Ti'6N'TEs-i~S.· . · NAME Include interval tested, pressure data, all fluids recovered and gravi.t~y, MEAS. DEPTH TRUE VERT. DEPTH GOR: and time of each phase. Top Upper Sand 7'533' 5947' N/A Base Upper Sand 7553, 5965' Top Lower Sand -7665' 6065' Base Lower Sand 7796' 6183' . 31. LIST OF ATTACHMENTS " None 32. I hereby certify that the foregoing is true and correct to/z~l~est of my knowledge Signed (~ ~ ~ ! Title Associate Engineer Date // \ I~N TRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, IncJl . Posl Office Box 100360 . Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 22, 1985 Mr. C. V. Chatterton Commi s s i Oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton- Enclosed are Well Completion Reports for the following wells' ~D-.5 .~ 2D-6 2D-8 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU5/L50 Encl osures ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ?-~ STATE Of ALASKA ALASKA ~ AN D GAS CONSERVATION CC ,VIlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-126 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21157 , 4. Location of well at surface 9. Unit or LeaSe Name 168' FSL, 550' FEL, Sec.23, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1351' FNL, 1365' FWL, Sec.24, T11N, RgE, UM 2D-5 At Total Depth 11. Field and Pool 1171' FNL, 1434' FWL, Sec.24, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) · 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 126' RKB ADL 25658 ALK 2584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 09/09/84 09/17/84 09/28/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7990'MD,6361 'TVD 7895'MD,6274'TVD YES [] NO [] 1870 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run DIL/FDC/CNL/GR, Gyro, CBL, Temp. Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 116' 24" 224 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3823' 12-1/4" 1075 sx AS Ill & 685 s: Class G 7" 26.0# J-55 Surf 7971' 8-1/2" 625 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7742' - 7722' 3-1/2" 7626' 7379' & 7606' 7722' - 7702' w/4 spf 7702' - 7700' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7688' - 7678' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL usED See attached Addendum. 7578' - 7534, w/12 spf 27. N/A PRODUCTION TEST Date First Production [ Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.k. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 GRU5/WC30 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. .. 30'. ~ , . .~, ~'~oLO.%~:~'~R~'E.'~:'" ~'.~..~.~:._: ~ .i.'.~'~ ~-.~:~ ..::'. :~ :-:..? .~.~ ~.. ~:. !-.~_FORM^T,~N~ES~'~'.:.''' '~' . . .~. · NAME Include interval tested, pressure-data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper 5and 7533' 5947' N/A Base Upper Sand 7553' 5965' Top Lower Sand 7665' 6065' Base Lower Sand 7796' 6183' 31. LIST OF ATTACHMENTS Adrl~nd,,m 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~.~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service .Wells: Gas injection, water injection, steam injection, air irljection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate-"none". ARCO Alaska, Inr~'' Post Office ~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/23/85 Transmittal No: 4925 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items. Please acknowledge receipt return one signed copy of this transmittal. BHP REPORTS & SEQUENCE OF EVENTS 2B-l~3' 10/16/84' '"Static" SBHP 2B-i~~- 10/17/84 " " 2B-2~~-'~ 10/17/84 " " 2B-6t ..... - 6/02/84 " 2B-101~ 6/02/84 " 2B-11~ 6/03/84 " 2B-12N~- 6/02/84 " 2B-14~~ 10/28/84 " " 2B-13~ 10/28/84 " " 2D-5-~~ 10/05/84~ " "' 2G-l~ - 9/21/84 "Static/G. Ring" 2G-2 *~-~ 9/22/84 " " 2G-3 .~ 9/23/84 " " 2G-4 ~ 9/23/84 " " 2G-8 % .... 9/30/84 2F-15,'" 4/13/84 2X-13~ "12/18/84 2X-14~ 12/21/84 .2X-15~ .... 12/23/84 2X-16)'~12/21/84 . . "St&tic/G. Ring/Tag" SBHP Receipt Acknowledged: lB-3 ~ ~-~"' 6/26/84 1B-4A~' :.6/26/84 · lB-6 % . 7/01/84 1E-2 ~-" 6/22/84 1E-7 % ~ ~/14/84 1E-4 ~-- 10/15/84 1E-12 ~ ..... 6/24/84 1E-20%-' 6/23,22/84 1E-22~ ~- 4/23/84 1E-25~~-~ 6/23/84 1E-25~ 11/'09/84 1E-29'$ ...... 6/23/84 1E-29} 10/14/84 1F-4 ~ .... 9/14/84 1F-4 ~'~ 9/14/84 1F-7 '~ ~' 7/05/84 1F-11 ~'~ 4/.25/84 1F-14~ ..... 2/07/84 1F-15%-- 2/14/84 1G-i' ~' 6/29/84 VlG-i~ -- 9/13/84 /1G-3 '.~' 5/16/84 vlG-5.~' 6/29/84 1H-4 ~ 6/24/84 1~-3 +- 1/21/84 1Y-51~' 5/06/84 1Y-9%~ 5/06/84 1G-14.--" 1/12/84 1L-2e? . 10/21/84 iL-3 -,~- Date: DISTRIBUTION B. Currier BPAE Chevron D & M Drilling Geology Mobil NSK Ops. W, Pasher G. Phillips Phillips Oil J. Rathmell SBHP " "Static" " "Static" II ,I II I! II I! II I1 I! " "Static" I1 II II 11 II II 11 II I! I, Il II ,1 ~ /~cat Sohio Union Well Files .~ - ARCO Alaska, inc. Post Office [""-"~ 360 Anchorage, A,aska 99510 Telephone 907 277 5637 RETURN TO: Date: 12/_ 27/84 Transmittal No: 4940 ARCO ALASKA, INC. ATTN: Records Cler~ ATO-1115B c' Box 100360 horage, AK 99510 ' · ~../Transmitted herewith are the following items. and return one signed copy of this transmittal. Please acknowledge receipt OH FINALS/ Schlumberge,r ZD-5 DI .- sFL/GR " 2"/5" Density Neutron '-'Poro" "2"/5" " " "Raw" " C~erlook ~ Surface Gamma Ray .... / ~ 2B-15 2"/5" Dens~-~--M~'~'6-~ "Raw" / · . / " 2"/5" ,, ,, ,,PorO,, 2"/S" DIL-SFL/GR CPL CYberlook " * Surface Gamma Ray * NOTE Rec'd No Sepia 9/18/84 Run 1 3836 - 7962 9/18/84 " 7300 - 7'921 9/18/84 " 7300 - 7921 9/18/84 " 7350 - 7950 9/18/84 " 7300 - 7921 9/16/84 " 7450 - 8041 9/16/84 " 7450 - 8041 9/16/84 " 3398 - 8088 9/16/84 " 7450 -~8040 9/16/8'4 '-" 7450 - 8041 /cat Receipt Acknowledged: DISTRIBUTION B. Currier BPAE Chevron D&H Drilling W, Pasher . Mobil Phillips Oil NSK Ops. J. Rathmell Alaska 0il & 6as Cons, Commission Sohio Union Well Files ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompan¥ ARCO Alaska, Inc Post Office ~Ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 20, 1984 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2D-5 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2D-5 Well History covering the completion details. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L15 Enclosures RECEIVED DEC 2 7 1984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALAS STATE OF ALASKA Cji. MISSI°N CONSERVATION Classification of Service Welt · Status of Welt GAS E3 leratOr Alaska, inc. &K 99510 dress Anchorage_~, p. O. Box 100360' 38' FSL, 0' FEL, Sec.23, TllN, RgE, UM Producing interval R9E, UM Atl~¢~, FNL, 1365' F~IL, Sec.24, TllN, At Total Depth FVIL, Se 1171' FNL, ,etc.) RKB dded 7895' 7990' ,gs Run :iai No. ate ComP., survey NO E3 1870 ~mber 84-12( umber ~qame ,umber poor Kuparuk River Fi eld Kuparuk River Oil pool offshore feet feet bAD flotations open to interval, size and number) 7742' - 7722' 7722' - 7702' 7702' . 7700' 7688' . 7678' 7578' - 7534' wi4 spf w/12 spf .oduction Tubing pressure NoNE and pROD L-BBL L-BBL :, etc.) 'ID :orr) )re chips- RECEIVED OEC Alaska Oil & .Gas Cons. Commission Anchorage Submit in duplicate Form 10-407 Rev. 7-1-80 ORU3/~Cl 1 CONTINUED ON REVERSE sIDE 29. ~:,.... ~ : ' . '~* i .... ' . O, : . . . t. - -" '. ..... -' GEo~:OG:I~-'M~,I:IK'~:R's :-:: '" :~' :: 'i' ¢::: : :i''t' :;¢-': '"".'. ? '-.}" :'.;-' :' "' "~ "' ":'"F~MATi'ON:T~:ST~;: ." ' · ~- ,. :'-" · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR,and time of each phase. Top Upper Sand 7533' 5947' N/A Base Upper Sand 7553! 5965' Top Lower Sand 7665' 6065' Base Lower Sand 7796' 6183' 31. LIST OF ATTACHMENTS W~ll Histnry; Cyrn.~.oni~. S. rv~.y (? 32. - I hereby certify that t~e foregoing is true and correct to the best of my knowledge Signed ~-J~l~J~--'' .~'),.U,~tc:/L~- Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other eleVation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". i : . Dally Well History-Initial Reline,t: ' ~0 ~~!~; ~ ~ ~ e~e ~n~u~ d~. only. :~: Alas~-~ : :~: ::~ ~~q~??- ~ North Slope Borough [ Alaska Kupa~~ ' ~L: 25658 ~ [ 2D-5 Aut~. or ~.O; no~ : ~tle '~ :g02071: Drill, Complete & Perforate Parker 191 API: 50-029-21157 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate ]Hour Spudded 9/9/84 Complete record for each day reperted Date and depth as of 8:00 -m. 9/10/84 9/11/84 9/12/84 9/13/84 The above Is correct . ,~ Signature __ //F / 1100 hfs A.R.Co'e W.I. ' 56.24% Prior atatue If a W.O. 16" @ 116' 1378', (1262'), DD Wt. 9.8, PV 17, YP 20, PH 10, WL 12, Sol 6 Accept rig @ 0715 hrs, 9/9/84. NU 20" & diverter sys. Spud well @ 1100 hrs, 9/9/84. DrI & surv 12¼" hole to 1378'. ' 500', Assumed vertical 660', 3.2°, N25.5E, 659.92 TVD, 4.47 VS, 4.03N, 1.92E 964', 13.1°, N29.5E, 960.58 TVD, 46.73 VS, 41.22N, 21.97E 1116', 18.3°, N28.5E, 1106.86 TVD, 87.80 VS, 77.23N, 41.91E 1266', 23.1°, N25.5E, 1247.13 TVD, 140.80 VS, 124.45N, 65.97E 16" @ 116' 3450', (2072'), Drlg to csg pt @ 3726' MD Wt. 9.7, PV 20, YP 24, PH 9.5, WL 10.7, Sol 7 DD, drl & surv 12¼" hole to 3450'. 1418', 28.5°, N27.5E, 1383.93 TVD, 206.92 VS, 183.63N. 95.48E 1662', 37.8°, N27.5E, 1587.94 TVD, 340.27 VS, 302.46N, 156.02E 20B3', 40.8°, N30.5E, 1873.59 TVD, 576.73 VS, 510.41N, 268.96E 2523', 42.9°, N32.5E, 2237.55 TVD, 903.36 VS, 790.97N, 440.38E 3016', 44.9°, N33.5E, 2593.98 TVD, 1241.39 VS, 1074.87N, 627.11E 9-5/8".@ 3823' 3840', (390')., NUBOPE Wt. 10, PV 16, YP 9, PH 9.5, WL 11.2, Sol 8 Drl & surv: 12-1/4" hole to 3840', 10 etd short trip, C&C f/csg. RU & rn 98 its, 9-5/8", 36#, J-55 ERW BTC csg w/FS @ 3823', FC @ 3752'. M&P 1075 sx AS III, followed by 685 sx C1 "G". Displ using rig pmp. CIP @ 0145 hrs, 9/12/84. Perform top job w/75 sx AS I. ND dive,re,, NU BOPE. 3262', 45.4°, N34.5E, 2767.47 TVD, 1414.19 VS, 1219.46, 724.63 3790', 46.5°, N34.5E, 3132.43 TVD, 1792.03 VS, 1534.90, 939.26 9-5/8" @ 3823' 4380', (540'), Drlg Wt. 9.2, PV 8, YP 3, PH 10, WL 12.4, Sol 3 Fin NU BOPE & tst; OK. PU BHA, TIH, tag cmt @ 3748', tst csg to 1500 psi; OK. DO cmt & flt equip + 10' new hole. Conduct formation tst to 11.5 ppg EMW. Drl 8½" hole f/3850'-3994', TOH, PU Neyrfor, TIH, drl 3994'-4380'. 3964', 46.8°, N35.5E, 3252 TVD, 1917 VS, 1639N, 1012E 4087', 45.2°, N33.5E, 3337 TVD, 2005 VS, 1711N, 1062E 4305', 45.1°, N31.SE, 3491TVD, 2158 VS, 1842N, 1145E I.Date Title 10/09/84I Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Inltructionl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICountyorParish IState Alaska ~ North Slope Borough Field Lea~ or Unit Kuparuk River ADL 25658 Date and depth as of 8:00 a.m. 9/14/84 9/15/84 thru 9/17/84 9/18/84 9/19/84 The above iscorrect Signature ~~~ For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Complete record for each day while drilling or workover in progress 9-5/8" @ 3823' 6700', (2320'), Drlg Wt. 9.4, PV 15, YP 10, PH 10, WL 12, Sol 6 Drl & surv 8½" hole to 6700'. 4614', 45°, N30.5E, 3709 TVD, 2376 VS, 2029N, 1258E 5054', 42.3°, N26.5E, 4025 TVD, 2682 VS, 2297N, 1405E 5425', 41.4°, N19.5E, 4300 TVD, 2930 VS, 2523N, 1508E 5868', 41.1°, N18.5E, 4633 TVD, 3220 VS, 2799N, 1604E 6581', 39.8°, N17.5E, 5175 TVD, 3680 VS, 3238N, 1753E 9-5/8" @ 3823' 7990', (1290'), C&C hole Wt. 9.8, PV 10, YP 4, PH 8.5, WL 11.5, Sol 8 Drl & surv 8½" hole to 7544', losing fluid. Mx & pmp mica pill, monitor hole. M&P LCMpill. (Accum fluid loss = 1500 bbls) Drl & surv to 7990', TOH f/bit chg, hole taking fluid. TIH to circ LCM pill & cond hole. 6802', 39.6°, N16.5E, 5346 TVD, 3819 VS, 3374N, 1793E 7240', 33.2°, N20.5E, 5698 TVD, 4076 VS, 3620N, 1875E 7840', 23.1°, N19.5E, 6226 TVD, 4357 VS, 3886N, 1972E 7955', 21.1°, N22.5E, 6333 TVD, 4400 VS, 3926N, 1988E 9-5/8" @ 3823' 7990', (0'), C&C hole Wt. 9.8, PV 19, YP 13, PH 8, WL 9.6, Sol 6 Rm to btm @ 7990', spot LCM pill, TOH. RU Schl, RIH, hit bridge @ 5694', POH f/cond run. TIH, rm 7841'-7990', C&C hole. 9-5/8" @ 3823' 7990', (0'), LD DP Wt. 9.8+, PV 17, YP 10, PH 9.5, WL 10, Sol 9 27 std short trip, circ & spot LCM pill, TOH. RU Schl, rn DIL/FDC/CNL/GR. TIH f/cond rn, wsh f/7639'-7859', rm 7859'-7990', circ & spot LCM pill, TOH. Alaska IWell no. 2D-5 IDate ITitle 10/09/84} Drilling Superintendent RECEIVED O £C 2 7 198 . Alaska 0il & Gas Cons. Commission AR._ O oil and Gas Company Daily Well History-Final Report Inalmctlena: Prepare and submit the "Final ReFerl' on the first Wednesday after allowable has been assigned or well is Plugged Abandoned, or Sold. "Fiftel Raperi" should be submitted a so when operat ona~a[e=suSPended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, repOrt completion and repreSerl~;teSt data in blocks provided. The "Final Rel~rt" form may be used for reporting the entire operation if space i~ available. I Accounting cost center code District ICounty or Parish State Alaska I North Slope Borough Alaska Field ILease or Unit I Well no. Kuparuk ADL 25658 2D-5 Auth. or W.O. no. ~Title AFE 902071 I Drill, Complete & Perforate Parker 191 API 50-029-21157 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 9/20/84 IA.R.Co. W.I. 56.24% lO.to 9/9/84 Complete record for each day reported Iotal number of wells (active or inactive) on thiss est center prior to plugging and I bandonment of this well our I Prior status if a W.O. I 1100 hrs 7" @ 7971' 7990' TD, 7895' PBTD, RR 10.2 ppg Brine Fin POOH. RU & rn 203 its, 7", 26#, J-55 ERW BTC csg to 7971'. Cmt w/625 sx slurry. Displ'd w/10.2 ppg br, bump plug. CIP @ 2015 hrs, 9/19/84. ND BOPE, instl lower pack-off & tbg spool. RR @ 0400 hrs, 9/20/84. Old TD I New TD 799O , I Released rig J Date 0400 hfs I 9/20/84 Classifications (oil, gas, etc.) Oil PB Deplh Kind of rig RECEIVED DEC 2 7 41aSka Oil & (~as Cons. Commissior~ Anchorage Type completion (single, dual, etc.) Single 7895' Rotary Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity ~llowable Effective date corrected Signature Date Title 10/09/84 For form preparation and distribution, see Procedures Manual, Section 10, Drillin$ Superintendent S UB-$ URFA CE DIRECTIONAL SURVEY ~-~-~ UIDANCE ~-~ONTINUOUS ~"] OO l Company Well Name Field/Location ATLANTIC RICHFIELD COMPANY RECEIVED DEC 2 7 Alaska 0il &(]as Cons. CommJssDn Anchorage 2D-5 (168' FSL, 550' FEL, S2'~.,, T11N, RgE, UM) KUPARUK~ NORTH SLOPE, ALASKA Job Reference No. 69557 Logged By: MURTLAND Date 0CT-15-84 Computed By: STEVENS 21,I- 5 ARCCJ A!.,ASKA, 20' 5 KUPARIIK 't' R I.I F MEAStiR[<I.) VER'i']C I') E P 'I' t! [.) E !' 1.' 10(!, O0 10i), 200. OO ZOO,, 300~00 299, 500, (}0 499 600. (>0 599' 700. O0 699. ~ 860,0u '199, 900,00 898, I. 00(). O0 995, 1. 1 O0, O0 1. 092, 1200.00 1, 1,8fl. 1400. o0 1369, 1600.00 1540, 170o, O0 1619, 1800,00 1697. 1900. OU :17'~4, 2100,()0 ] 926, '22o0. (,0 2 l) () .1 . 2300, O0 207h. 240().00 2150, 2500.00 2223. 2600.0u 2296, 2700.00 236q. 2BO('. ("'~ 244./ . 2900.o(; 25'14. 3000. r.(~ 2b~tb. 3100,(,0 2bbb. 3200.00 2727. 33(.~0.0{~ 279t. 340().00 2807. 35(;0. ~ 29~a, 3000' O0 30o5, ]800.00 31q2. 39uO,(,U 3211, & ' ' ,S t..~ h k A (': U ~ P U T A T I f:~ N iF,'I:t':HPFtI.,A'I'EL.? VAI.,i,I[!'.;; ff[']R AI., VERTICAL DEVIA']r]'oi~ AZ[.NtJT t:. f..t H f,,') g (; ',,',,11 i',,; 1,'~ t:': {; i,: I' V ~: f,'T ] (.] A |., I) i ) [.; j., t., [', $1<CTIQN F' l'; E i' ['., ii: C; t ] 0 () U ,. f.)f.l i), 00 0.06 l.,~. 61. 0. (,)7 0,14 -0.08 0,13 -0. ,3 1 (.~, 20 -0. A5 0.44 ~). 51, 2,27 5.46 2,90 30.65 3,82 b2 2459.[42 4,~ ..t,'t ~',,33 5b g 51 2601,51 4P b i~ 34 17 26 2741.26 46 12 ,'~36 53 3~ 7~,1t~.3~ 4n 26 ¢.,35 ~ 1,9 2B'19.19 ~4() 37 N 35 ltl 72 29,t7.72 ,4t~ '~ ~'~.~b 2~ 2i~ 301t,,2F 4~ 39 ~ 35 42 E 5t. 87 ,'~. 35 II 1..4(; 3,'17 149,41 3.53 1~2.76 4. 19 24] .69 4'.22 296,46 4.52 356.4b 2,09 419,68 0,36 4B3,41 O,5h 547,8(.) 0, b3 b 12.90 0,33 6'1 B, b l (>, 7 4 744.95 1..03 8 ~iO. 2(';' 9,b3 016.51 0,38 153.66 0.90 1222.9! 0.72 1292.67 o, 25 1362.70 O. 24 ]4~3.o7 o.64 1504.25 {.), 39 1647 . 37 O, 34 l'l] 9.29 0. ]0 1791 ,~3 0,28 1862 ~ 5.] 0,85 ,, PAGE 1 DATE Kt<bLY Fi:~5!t]'l'~(; EI,,~EVAIIONI 126,00 FT k;' i',~ G I ~ E t:, t{; 1'4 U I.t I' l,., A a £) h', E A, 5 t,i R F; I,', i,~I,.;C'TANCiUI.,AR C!~(']I,(L)II't/~TE,5 t'lORIZ, DEPARTURE ["' k,.; k:'t: F P;~;'I' f'EET DEG MIN O,tb n 0.19 ~ O, N :49 8 ~ 0 ,b4 t', 2,~t1 ~ 2,55 N 70 41 0,92 ~ 2,89 ~ 3.03 N ~2 20 W 1,91 a 2,70 ~ 3,31 N 54 47 ~ b.34 ~ 0,50 ~ 6,~6 N 4 32 W 15,(~6 ~, 4.43 E 15,70 N 16 23 g 28.29 N 11,92 E 30,70 ~ 22 51 E 46,92 i~ 22.13 E 51,87 n 25 15 6.'. ~u.g, 7 ;~ 50,99 E 1,11,42 N 27 14 E 132,07 ,~'~ i:,8,18 E 149,43 ~'~27 8 E 1.71.87 i~ ~'1,30 E', 1,92,77 a 26 55 E 215,Ut) .~'; 110.36 E 241,72 N 27 9 E 263,1'1 ;~ 136,63 E 296,53 N 27 26 E 315,i{~ t~ 1{:~5,56 E 356,59 1~ 27 39 E 371.09 N ~96,39 E 419,86 N 27 53 E q26,"i7 :'~ 22'1,b9 f 483,66 m 28 4 E 4t, t,i'),t ,~ 259,05 F 54[{,12 ~ 28 12 E 539,t-~b N 290.98 E 613.30 N 2b 19 E 591,1.3 a 323,23 t: 679,00 *~ 28 25 E 654.85 N 356,40 g 745'55 N 28 33 E '112.9'1 ~,, 390,Ub fl 813,08 N 28 43 [; 771,]0 N 426,05 E 881.15 N 28 54 E f~29.,19 f,~ ~61,6~ E 949 32 i~ 29 5 g 8~7,9b N ~9;,70 E ~0~7' ,92 N 29 ~6 E 940,rib ~ 534.U~ f. 1086,73 N 29 26 t ~O04.64 ~ 571.17 E ~155,65 N 29 37 E 1,0t, 2.91 a t)Og.bB I< 1225,30 n 29 50 E 1121,1~. ~, (,49,15 6, 129b,b5 N. 30 4 E 1179.b6 i'~ 688.90 g 1366.08 a 30 17 E 123~,2'~ ;'~ 72~,11 ~. 1437,00 N 30 29 E 1297.4~ N 770.13 g 1508,79 ~i 30 41 135o,t{~ r,i htl.,59 F. 1. b8i.).8~ I'~30 53 E 14~5.98 i'~ Ub].32 E 1653,23 N 31 4 E 1534' .6b ~ 937.'73 E 179~,47 N 31 25 g 1593,4'/ i~ 979,9U E 1870,05 N 31 35 g C: [,~ M P I~ T A T 1. 0 f.~ M ~;A$1.i RE:l) t> E l:" 'J' ti 400 O, 0 4, '1, 00.0 g 4. 20 t). 00 43()0 , O0 4400. O0 4500. O0 40 U (T,, 0 0 4700.0 (., 4900. 5000. 52O0. O0 5 J 0 (/, ("i 55 (.) (). C. 5~()0 . O0 5 '1 i) (). 5 B 00.00 5900. ~, 6'(') () 0. ~ 0 6200. 6300. 6400.00 6500. O0 6600. 6700.00 68 () 0. t' ~" 6~00. O0 7 () 0 U. 0 O 72o0. 73ou. Ot~ 7400. 7~00. oo 7800.00 7900. o (',. V t~:R'l' 1 CAI, D [!: t'-' T !.~ 32'19.83 3349.13 3,i. 1CJ. 59 3490.14 ]56,i, b 1 3631.49 3 'l 02,0 ,i 3'772.al 3843 . 6 () 3914.B2 39a8. I 1 q 001.7 4135.67 42 ()9,3 4283.24 435 ii;, 44.33.23 45(.) H. ~4 4583,49 4809. q885 25 4960: 92 51 U 9 4 b2o{, 107 549 fl. '] 4 5660.54 5744 . 583U.23 59 17 , 1 6186.9~ lu,~q'gkPI.,t!..,'~TE!:' V,~l.,ul~:,'.j IF(.)ti [':VP]~,: IL., PAGE 2 I~A'I't~.; OF 5tiRVE¥; 21-SF, P-84 Fi }",: [,,, [,,, ~ i.~,L',St, llr,iG EI..,F. VATICIN: 126,00 FT ~:r,,!(;,[Ht, iER; F~UIR'.I'LAND 3!t.i3,~3 46 43 ~,i 35 :Iii ~.; 1.934:,39 1,(,2 1.652,'12 ~v 1022,22 3223.13 45 21 a 32 43 E 2005.78 1,67 1712,33 N 1,062,74 3293.59 45 8 ~'.~ 31 4g ~: 207t,,3'1 O,.Ju 17'12,4.2 N 11~0,49 3364.14 45 5 N 3J 24 E 2146.93 O,1B 1.~32.79 n 11.37.61 3434 ~1 45 3 ~,.31 14 E " . 3505.49 45 4 t% 31 13 E 2287.SS 0.34 1953.72 ,~ 121.1.07 35'/t,.0~ 45 15 t'.~ 31 '7 E 2358.49 U,54 2014:,35 ~.~ 1247.77 3646.61 44 42 N ~1 3 E 2429.0H 0.51 9076'(11 h 12B4,36 3717,,.,0 4q 48 i~ 30 53 F, 2499,27 0,3H 2135. J9 r,,; I320 37HB.~2 43 41 ~ 29 56 E 2569.26 3.41 2'195''18 N 1356 38o2.1.1 42 3b i,,t28 24 E 2637.21 ,3g..~5.79 42 2,] ;,: 2t) 1 F 2704.H0 .t009,07 42 27 a 25 56 f., 2"172.2C, 4~")H3,'~! 42 ,~1. {:,~ 25 5~ ~: 2839,85 4157.24 41 54 N 21 17 E 2907.14 423P.C,*; 4~ 17 ,; 18 10 E 2972,90 4307,23 41 19 N 18 15 E: 3038,22 ,~382,'~4 4! lq ~'.' 18 .1.4 F 3103.60 4457,49 41 l.b h 18 5 E 3168.93 4.532.79 41 7 iq lt~ 3 ~., 3234,04 4i~oi,.16 4~ 5ti ~ 17 bq F, 3299.1(., 4683.~7 40 55 :N 17 56 E: 3363,97 4'159.2b 4U 50 n 1'1 49 E: 342~.76 4B~4.92 40 48 N 1~ 42 E 3493.42 ,i91,(,~,o5 oO 53 1'~1.7 39 F '355t~,02 498b.56 40 7 ~ 17 32 f: 3622.35 9063.:1('.' 39 47 ~' 1.7 ~4 L 36~b.62 51~0.u7 39 45 n 17-25 E 3'149.07 b21. C.H'i 39 50 r,,1't 21 k; 3812.3'y 5293.~8 i9 4 i~ 17 lO L. 3875.36 5372.34. 3'1 t0 N 1'1 0 fl 3916.5H 545'J.43 35 .%6 N 16 53 ~: 3995,65 5534.54 34 2 t,~17 20 E 4052.01 501.~.'3,~ 31. 66 i',1'1 z{H ~. 4106.93 5704..23 29 46 l'J19 22 E 4156.67 6791 ,'/9 2;~ O I',2U 50 ~; 4204.6H 5~a(>.bl 2o 55 N 20 .il E 4250.61 ht)60,9(, 2'~ 47 ~i 21 9 F 433~.44 6152.,7 2~ 2H ;'~21 b [: ,~]'/6.14 1..76 U, ,% h 0, 6,28 ('.), 9 O 0.25 (~.20 0.45 i.), 36 t) o 29 l~..1 } (.), 10 (.,, ':)5 1.01 1.75 1.06 1.30 1,35 2.43 1.44 I.. 22 0.76 I ,.~2 2,J1 0,00 2255.22 23:t 5,45 2376, U6 2436. a 1 249 8.0 o 256U,~1 2623.48 27 ~ 8 , 8 '1 2 f~ 't 3,92 2936.27 299 8,59 3060. ~5 3123, !,0 32.b, 14 33U7,30 330b, h2 3429.39 36(.i 0, ~o 3~52. 4d 3701, 05 3'/89.5u 3Big,B9 3907. O U DEPART'UAE AZIAtJTH DEG 1.943 21.57 2227 2369,50 ~440.]4 ,63 E 2510,77 ,40 E 2580,94 1369,52 g 2648 }42(),19 F': 2716 1449.68 E 2783 ]479,32 B: 2850 1.507.39 ~2 2917 152~,~2 E: 2982 1549,42 E 3046 1570,10 E 311i 1590.68 E 3175 Ifil,09 ~ 3240 92 29 74 62 46 86 39 93 ~2 n 31 38 g n 31 31 ~: N 31 23 g N 31 15 k2 N 31 6 g n 30 50 £ N 30 33 N 30 18 E N 30 n 29 48 E 1031,41 P.'. 3304.68 .1.651,a4 E 3368,92 1./:,71,7'1 E 3433,13 1691.71 E 3497,24 1,71.1, 55 E 3561,34 175u,53 t 3688 06 1't69,8t E 3751:14 17~9.u0 P: ]814,12 ~07.94 E 3876,77 N 29 34 E n 29 21 g ,~ 29 8 fi.'.: n 28 55 Ii; N 28 43 E N 28 31 E N 28 20 g n 28 9 E ~ 27 5B £ N 27 47 E N 1~26,23 E 3937,72 {~ 1~43,62 f: 3996,56 N 18b0.45 E 4052.73 !'~ 197t).86 El 4106,49 N 1~93,11 E 4157,12 I~ 19i19.80 E 4205,05 a 192~.13 E 4250.92 a 19,1,97 ~ 4294,94 N 1957.17 E 4336.66 r; 1971,53 E 4376,33 27 37 £ 27 28 g 27 19 g 27 11 E 27 5 g 27 o ~: 26 56 g 26 52 E 26 49 E 26 4~ E L ........................ J ARCO ALAISK A ~, KUt:'ARIIK $ E C T i 0 I~,i ~ E V ~', R I '1' ¥' [-' E', E' T D ~: ~:; i 1 U () r.4 E A ~ U R E 1"~ V E R T 'l C. A I.., V t:: R 'l ,t C A l., 1') E V ! A T [ 0 :'~i A Z .1,1~,~ [; ',t' 7 9 .q C) ,, (.i (") ~', .½ 6 1.2 3 o 2 .~ 5.2 3 2 3 2, a ;',, 2 ! ~!, f:.; 4 q 1. 1.. 8 4 PAGE 3 126,,00 COiaPUTATI. iIN [)A'fi::: 11. t; E P T ~.! [.', E P T n I.> t!: P 1 H D E G P,',..t i~ 1~ E t..~ ,:,.i I I.)ATId ::iii.' 5UR¥EY: 21-SEP-8,t ..[h,'!I:~.,b:Pi~I..,i~TEL, ~Al.:.]t:5 ["0i'~ t.:V[::~'.; 1009 Vi::R'I].CAI, t..~J<::;~...,~,(; E~,:CTA,::(;L~I,,,AP: CiJCJRt:),II~AI'E$ tJORI~. DEPARTIJRE ~ECTION SEVERITY aORTH/~UilTH ~:ABT/WE~T DIST~ AZIMUTH 0,00 3,35 0,53 0, '/2 :! l . 78 I , 30 () ,00 126,00 FI ~,~,00 t"~ 0,00 g 0 O0 N 0 0 E 4b.92 ~',~ 22,13 g 51 5 15 E 1062,91 ~ 009.58 ~: 122530 N 29 50 g lUb2,/2 n 1022,22 ~'. 1')43 ~0 2255.22 ,q 13~9,52 E 2648 92 N 31 38 g 3g~9,6.t ~ 1~26,23 E 393772:' N 2~ 37 F 3940,b2 ,~ 19~4,44 g 4411 99 ARC't~ A[~ALSKA, 21)-5 K U P A R [', K M£ASURED L) [!; P '1 H · I) ATE: 11'0C'.t-t~:4 0 34 126 320 426 526 626 '726 826 . ,0 I) o01 ,01 ,03 , 24 . F()P, ~,V[;:h,, 1o0 i"EI:.,T ~} VER'I'TC, AI,,, VIi'RTICAL DEV1A'r[t]~N AZI 13 l< i) 'T .!.! i.) ,< P'] t.I DEG 'i2b,O0 -100,00 U, 00 1, ~',~O. O0 '200.00 3OO. O0 4 U 0,00 b 00,00 (:, t; (,T:. '10 (>. 00 928 1031 1135 12,t2 1351 14o4 1582 1707 1837 19~i, 7 .37 . b I . 2'9 . 6'1 . ri 8 .78 .50 120 226 426 526 626 ? 2u 826 20 9 2232 2366 2503 2640 2778 29i~ 3056 3147 .19 .02 .17 .41 .53 .~7 .41 92 b 102 o 1126 ] 22t'. 1.326 14 2 ~, 1526 1626 1. '726 · t,) i') . O0 , 00 . O0 . O0 ,00 . UO , 3484.q~ 363U 32 3776~27 3921 .43 4060.99 4209. 4 350.77 44q2.22 4634. O8 477b. i 202b 2226 2320 242h 252~:~ 2 't 2 2f~2b , O0 . (; 0 . O0 . l'.) C, .00 . O0 . . U 0 . O0 . .0 U · 0 0 , UU , 2926, 3020 3126 3320 352b 3720 3t). 07 3.56 59. fi5 3. (.)5 89.8O 3.25 i. 26 . ~7 2,8~ 1'71..15 3.26 223.'/2 4, J. ~ 28b. 77 3,59 361.. 35 :1 . ~ 1 443.33 O. 1.5 526,6 ] I,l, 41 r,,2~ l<~ F, 612.37 N 29 42 E: 699.66 ",,30 ,~a F,: 789.92 a 31 20 g 882.48 {'~31 3'1 E: 975.72 i~ 31 57 E 1070.ll ~'~34 14 E 1262.29 ~ 34 ~7 E 136~.20 N 34 42 N 1461.74 ~, 35 1o B: IOog.lh h 35 37 g 1774.10 i,~ 35 '.]~ P.'.: lb'77,9(, i~ 33 45 E 1982.40 ,,,31 ab k'; 2Oo2.7/ I',31 18 g 2182.72 r.i31 5 E: 2]82.64 :,,3(., '39 F 2481,8:t I ,02 (',, ~9 0.54 ~.~, ~ 0 0.59 (),BO 0.43 ,'), 25 0.96 O. 7U U.45 0,59 0, b 5 3.84 t),34 0,21 0.41 0.24 {),41 P AG E 5 DATE ("it;' SURVEY; 21.,SEP-84 F..i~LI,Y bi,Stair';(,; ELE;VATION: ,:':, J (,; 1. i,; t-, [,5 R: ~,i U R T b A i',t D 1.2b,O0 FT O,UO I',, O,UO 0, U 0 i~ 0.00 u.2'? ;', 0,3'1 U.64 a 1'17 u.'li~ ,~i ],90 0.87 N 2,56 0,90 t,i 2,94 2.65 N 2.38 8. I 1 ,~ 0,52 33,U5 I'~ 14,53 53,7'2 r,, 25,93 ~0.05 N qO,70 l],2.oU r,{ 5B,13 152.51 N 77,71 199 20 i'~ 101,75 254"64, N 112,01 320.68 ~', 167,93 391,74 ,q 20'~,97 464.70 i~ 24B.'19 53Y,"~2 ~4 290,'12 ['. ~,15.5b N 333.70 E t,93.L9 !.4 379.32 F 773,20 I'~ 427,24 E ~53,(,~ i~ ~76.20 g ~33.V2 i'~ 526.0B E 1095,82 i~ 631.89 g ll7H.ql N t,B~,05 F 1262.13 N 745.58 g 1:347.71 i,~ ~05,34 ',l 434, t:, 0 ~q H~b.t)4 1520.62 ~ 92'1,67 1006. 1't h q~8.96 1692.bl N 1049.~7 ~7'1'1~ ~., 1103.~8 1B63.47 ~,~ 1.156.]~ 194~,U] F.: 120~.21 20ih.lO N 12b0.29 HORIZ. DIST, 0~46 N 53 1,3:3 N:::,6I 2 3,og N 71 3,56 N 41 ~,19 N 1.9,16 59,66 89'80 N 126~89 N 171,16 N 223,74 286,83 443,52 527,11 ~12 77 70O 19 790 63 883 44 97b 99 1071 ' 73 1167,04 1264.96 1364 58 1465:90 1570,00 1675,23 1781,25 ~86,19 1991,77 2092,7! 2193.07 2293 12 2393~73 2493,2'1 DEPARTURE AZIMUTH M I h 0 g 0 g 35 a 22 W 49 ~ 11 W 5O w 55 W 39 eL lB 54 E 23 44 E 25 4b [E 26 57 E 27 15 IE 27 0 E i~ 27 3 g N 27 24 g i,~ 27 41 E N 27 57 g N 28 9 E N 28 19 t: N 28 27 E N 28 40 E N 28 55 g N 29 10 E: n 29 23 g N 29 39 El N 29 58 E N 30 16£ h 30 34 E: N 30 51 E n 31 7,g n 31 23 E N 31 37 ~.: N 31 48 E . 31 50 N 31 49 E I~ 31 47 ~ N 31 46 g b 31 44 E J ARCU AI..,ASKA, 2. D - .5 ~'~ (')R ']11 :'i:, L i'] h, I'NC ,,, A l, A ,.% 1'c A ~ [< A ,'-1.' U R K D PAGE SURVEY: 21,-8EP-84 .1. 915 5051 5322 545'1 5590 5723 5856 59BE 6121 i r~ 't g R F () 1.., t,, 1' P; I) V A L, t,, 1~i S I"'0 t~: t,, V ['.: k~: 1. () ¢') F < r.' !' {] F 5 L,i t'; - 5 E A D I~: P T h 6253 63~5 6517 66.t7 6778 69o7 7034 7158 7278 '1395 V ER'[' I'CAt, [)EVIAT.[();,,{ AZINUTH 750 762 77 '3 784 79b 799 .85 4926.00 480().00 .56 5126.00 50()(). Of) ,67 522 u, 0 () 5 .1. :., 0 .0 3 5326, O0 5200 88 5 z~ 2 (), 0 f.) 530 {) .'77 552~,00 5400 , I 5 502<,, U 0 55t) 0 .33 5't26.00 b60(:.O0 v ER'FICA!., L., ~ ~ C-;.h [': {'.'.; Ht':C ! A L~ECT'I['IN S~,Vb:RJ'rY bit.j~TH I-" P: !,, T 1) r:. G / I t.) 0 t' 2579. ~2, 2, ~'1 2672.06 1,. 90 2 '? .6, 3. ] 5 ,.)..J 5 2855,11 1,07 2944.84 I. 1 () 3031 .92 0.25 3118.9~ u, 51 3205,7.4 O, 51 ']292.10 0 83 3377.9~ O' 07 346:] .59 0.22 3633,53 1 .43 3'1 l 5. ~1, ~). ~.~0 3798.44 (.}, 20 3t~H(). 2b 1,. 12 395'1 , :36 1 . 53 4094.51 2.47 4154.2t I. ~, 1 ,:i209,02 0.97 4260.43 I. 54 '; 3(";~, 73 I .29 ,i353.37 0,00 4. 396.6 ] U, O0 ,1411 .~4 O'OO 12b,O0 FT (,,7 ,,~ 13ol, 22(}4, . 228U,10 ,~ 1405, 236d.10 t', 1445, 245(},60 N .1485, 2533.89 r~ 151.9, 2617.~4 a 1547, 2784,23 N 2867.19 N ]629, 2949.75 N 1656, Ob ~, 2591,52 N ~1 41 E 69 E 2683 al 35 E ~1 E, 2774:58 N 31 24 e: 99 E 2865'-94 31 13 E 96 E: 2954~80 N $0 57 E 4.3 g 3040,65 N30 35 g 96 ~: 312~,58 N 30 14 E 21 E 3212,32 N 29 55 E 23 E 3297,75 ii 29 3~ E 01 E 3382.81 N 29 18 E 3032.1:,' a 1.0U2.53 E 3467,6b N 29 I E 31.14.~5 ,'~ 1'70~.77 ~,', 3552,33 m 28 45 E 3195,91 ;'~ 1'134,63 ~: 3636,31 N 28 29 E:'. 3275 "~ 75 E; 3718 08 i:~ 2~ 14 E ,,.: a 1759, , 3355.05 N 1784.79 E 3800,24 N 28 0 E 3508,7~ N ~832,37 E 3958,42 N 27 34 E 35'?7,~9 :~ la53,41 f: 4029,44 h 27 23 E 3641.4~ ~ 1873,~5 f: 4095,10 N 27 13 ~ 3bgU.'/t: N 1~92,31 E 4154,71 ~ 27 5 E 1911,30 g 4209,38 ~ 27 0 l= 19~'7.09 [~, 4308.97 N 26 51 E 1963,30 k. 4353,57 m 2b 48 g 191~,93 E': 4396,77 a 26 44 E 1984.44 E 4411,99 N 26 43 E 37 5 o 3'198 3 ~ 4 3 392b 3940 ARCO K i.I I~.' A ~',, ('.t R ',IP [, P 'd I? 13 E tf 5 A ii 1,') '.ro T A L 1) [!] P T H · C t{ M t:., U 'I'A T I (...J N [) A T if .', 1 I - t.,~ C'. 'ii' - ii ,4 P A G E 7 I;)~TE OF ,SdRVEY: 21-SEP-84 VA" KkjLL,¥ ~5[~SF!.II.~G ~;UE ,[i0~:~ 126,00 FT f~ tJR i~' ACE; L, UCATION AT' ,..)t~'!,';li~= lbse FSI..,, hbO' Fi;h, ~]C 2~B Tll~ RgE, U~ 'I'VD ~ECTANGULAR~ORDIN~TES , . :55(:' 5',3a,6b 381¢,.66 ~ l~i~ 45 E 605'I, 30 386a, 38 U 59 E 3905,22 ~ 1970 82 E 6235.23 3940,52 N {~$4 44 E ,, ARCU AI[,,~ASKA, Ii'~C, 2b- 5 11-[.~CT,-,84 PAGE OA'I'E OV SURVE¥I 21,t,'SEP-84 t'x L< t,, L 'Z ~, U $ [t i N G E t..., E V A T I 0 h: ~.: !.'~1G 1 ~"~ t:.: ii, t.,:: !'q U R T b A f,! D 5 R ECT A N 126,00 F'/4C E bOCATION ' SEC 23. Tl l , ~gE GUi, AR COORDINATES ' /SI3UTH 37t~0.73 N: 3769,40 N 3816,bb N 386B,38 N 3905,22 N 3940,52 N EAST/w [:ST 1915 34 g 191.8 64 E 19~ 45 g '19 59 E . 44 E ~, i': 1, L, L, Lt C A I.' I i' k U VERTICAl., 6301.23 U ~ SCHLUMBER©ER ARCO ALASKA, INC. 20-S KUPARUK NORTH SLOPE, ALASKA SEPTEMBER 2], 1984 TVW PLOT FROM OCT DATA JOB REFERENCE 69SS7 l 1 .,,-LL. SURFACE LOCATION: 168' FSL, 550' FEL, S23, T11N, RgE, UM VERTICAL PROJECTION sw PROJECTION ON VERTICAL PLANE OF AZIMUTH 2S SCAL£O IN VERTICAL OEP?H~ HORIZ SCALE = 1/1000 IN/FT WELL' 2D-5 SURFACE LOCATION: 16-8' FSL, 550' FEL, $23,T11N'RgE, UR HORIZONTAL PROJECTION NOR?H 4000 ~000 2000 I000 -lO00 -2000 -~000 SOUTH -4000 -6000 W£ST SCP, I.E : 1/10130 IN/FT ...... ..; ...... ,...,.~...~-.., .... ~..{~..L~.-;-t-~---i...L-.~ ~-~ '- ; ~'TF: i ~ ~ ; ! :-'-:--',"?'-r~ . .... ~ ..... ~'-'~ ; . ~ :'"~"i ~ :"~'~" , ........... ........ - : ...... : : ;...~_..~...?.~...~..?:...?..+ . t · ' ' ! i ~ ii - ' : : ; i ; I ' ::'= '' . f · ..? ....... ;.--;---i...; .......... ; ..................... 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[;'T *~;~;*~ .; ..... ~...;..~1 .... ~...;...;...;..~ ....... ;...~...; ......... ;.-; ....... ~-¢ .... , .... ;..~-.-;;~.; ........ ;--.~---; ......... ; ............. ?.-4---,-,-,--~--*---~ .... -~-.'-.-/-C-/-'/.'--.-'T--:---.--/'.~: ,~:.~ :x:::::::::::::T::]:::::::x:::::::::::::T:::::::::::::::F:::::::::::::::::::::::::::::F::::::::::::::::::x::]x:::F::::::::i:::::::...: ...... ~'"~::-i'':'''-:':~ ....... ! -5000 -4000 -~000 -2000 -1000 0 1000 781~ 2000ERST Su~geste~ form to ke insertcd in each "Active" well folder to d~.eck for timely ccmpliance with our regulations. Reports and Materials to be received by: ~ Date Required Date Received Remarks · c~~o~ ~~ ~s ia-~ 7~'~_~ l~_ / ~. -.. · Mud Log ~re ~ips '' . Core ~scrip:on ,Registered S~ey Plat . Inclina~on S~ey ,:[: '"~F: ........................... ~/~ , ~. . .7'-~ ,~, .~. Drill.~ Stm Test Re, ms .,ms ~= ~ ~ l ~ 0 7~~~ L: ..~- .. ARCO Alaska, Inc. Post Office '~'"' 360 Anchorage, A,aska 99510 Telephone 907 277 5637 Date: 11/27/84 Transmittal No: 4868 RE~ TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 T/ra~:Chorage, AK 99510 itted herewith-are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CBL ' s/Schlumberger/FINALS "Variable Density" "GCT/JB/GA" 9/19/84 " " " 9/31/84 ,I t, ,, ,, ,1 . ,l ,, ,, ,1 I, If I! ,I ti ,t ti tt ,I -1' ti 1! ti t' .- II It .. It tt ,l I1 Il I1 I1 II II 1t I! II I1 ,I I1 I1 II II I1 II I! }hznl "GCT" 10/07/84 " "GCT" 10/07/84 " "OCT/JB/GA" 9/31/84 " "GCT/JB/Ring 9/17/84 " "OA/JB/OCT" 9/19/84 " " 9/17/84 " '_'GCT" 7/21/84' " "GCT" 9/21/84 " "OCT/GA/JB" 9/14/84 " " 9/15/84 " · ,OCT/JC" 10/12/84 " " lO/15/84 " " 10/12/84 " " lO/13/84 " "GCT/JB/GA" 10/22/84 " " 10/22/84 " "JB/GA" 8/19/84 " " 8/20/84 Run 3 9/21/84 Run 1 "GCT/JB" 10/14/84 Run 1 " lO/14/84 " " lO/O5/84 " "OCT" 10/05/84 " "Perf 4''-~ 9/10/84 Run 2 5 z/2"/?Ps/J~" 11/05/84 Run 1 Acoustic "VDL/Signature/GR" /cat Receipt Acknowledged: B. Currier BPAE 6597 - 8292 ~2B-3/ 7000 - 8460 ~/2B-!6~/ 4950 - 7004 ~2B-13v~ 5750 - 8408 ---2B-14 5700 - 7970 ~2B-15 5348 - 6824 -2B-2 7250 - 9182 --2B-4 5055 - 6487 ~B-i~/ 6200 - 7866 ~2D-5~/ 6800 - 8954 --2D-6 5054 - 6650 -2DZ7/ 5597 - 8084 ---2D-'8-/ 5650 - 7951 --~2G-9~/ 5840 - 8524 --2O-ll~ 4940 - 6765 ~2G-10~' 5730 - 7950 --2G-12 5790 - 7814 - 2G-13 5989 - 8624 --2G-14'~/ 8650 - 9334 8650 - 9562 :-.-1F-6¢ 5692 - 6742 --1Y-5~", 5150 - 7252 71L-1/ 4500 - 6550 6800 - 7518 ~L-4¢. 7000 - 8210 --~L-3V/ 7961 - 8941 ~2V-8A DISTRIBUTION 6100 - 6992 ~1E-24 - /Date'//. ~ ~~ >'~f.~ Drilling W. Pasher State ~p.',::t "AK.' Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathmeli Well Files ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 23, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Monthly Reports Dear Mr. Chatterton' Enclosed are the Monthly State Reports for the following wells- 2G-9 1L-8 2D-6 2B-16 2G-10 1L-4 2D-5 2B-15 2G-11 1L-3 2D-4 2B-14 2G-12 1L-2 2B-13 2G-13 Sincerely, Area Drilling Engineer JBK/SH/tw. HILL/01 Enclosures RECEIVED NOV 0 5 l~ Alas~:.a Ol~ & Gas Cons. Commission Anchorage ARC. ti Alaska_ Inc. is a Subsidiary of AllanticRIchfleldCompany , ' ' .~'~.. STATE OF ALASKA ~--~. ALASKa, ,)IL AND GAS CONSERVATION C_ ,vlMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wellX~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 168' FSL, 550' FEL, Sec.23, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 126' RKB, Pad' 89' 6. Lease Designation and Serial No. ADL 25658 ALK 2584 7. Permit No. 84-126 8. APl Number 50-- 029-21157 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2D-5 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of September , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1100 hfs, 9/9/84, Drld 12-1/4" hole to 3840'. Ran, Performed top job w/75 sxs AS I. Drld 8-1/2" hole to 7990'TD as Ran, cmtd & tstd 7" csg. Secured well and RR ~ 0400 hfs, 9/20/84. cmtd & tstd 9-5/8" csg. of 9/17/84. Ran logs. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8" 36# J-55 HF-ERW BTC csg w/shoe ~ 3823' Cmtd w/1075 sxs AS III "G" cmt. 7" 26# J-55 HF-ERW BTC csg w/shoe ~ 7971' Cmtd w/625 sxs Class "G" & 685 sxs Class 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/FDC/CNL/GR f/7859' - 7990' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED NOV 0 Alaska Oil & Gas Cons, Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED/////~'~--~--~~~,~,~ TITLE A r~.a Dr il llno Fnnl.'q_~er DATE NOTE-F~e~rt or//'th~s %,~ is required for each calendar month, regardless of the status of operations, and must be Oil and C_~s Conservati~,~l'Commission by the 1 5th of the succeeding month, unless otherwise directed. Fnrm 1 C1-41-)4 "I I I / M D 1 1 fil'ed i~ duplicate with the Alaska Submit in duplicate ARCO Alaska. Inc. ~ ~,,:.- ;~.~ · -, ,. ;.~=c:.:- Date: 10/19/84 Transmittal No: 4774 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B p.O. B°x 100360 Anchorage, AK 99510 Transmitted herewith are the following items. ?lease acknowledge receipt and return one signed copy of this transmittal. LIS Schlumberger Tape~69576 ~ 9/29/84 ~ 1 3935 - 8641 ,, 3828 - 7988 ~9551 2I)-5 9/18/84 ,, 3388 - 8617 ~69574 29-14 9/26/84 ,, 2830.5-7939 ~-~9579 2G-13 9/30/84 ,, 2027 - 8493.5 ¢~9555 1I-3 9/20/84 /cat Receipt Ackm B. Adams D&M W.W. Pasher G. Phillips C. R. Smith State of Alaska F.G. Baker Drilling Phillips Oil Sohio p. Baxter Geology j. j. Rathmell Union BPAE Chevron Mobil ESK Operations R&D Well Yiles TO: Rec~ipt STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 ~ Gas Gonservatlon · 13001 PorcupLae Drive Anchorage, Alaska ffAS01 of the following material 026- -I~ which was transmitted via is hereby acknowledged: QUANTITY DESCRIPT%ON Fi,. -/'1, ~ ~ /':, ~ ~,e /I.~ RECEIVED: DATED: Copy sent to sender ~.s X NO _,. MEMORA qDUM Sta e of Alaska · ALASKA~OIL AI~D GAS CONSERVATION COMMISSION ~~t TO: ~ ~ / ~ DATE: September 14, 1984 _~/-/~ FILE NO: D 2I 30 THRU- Lonnie C Smith ~,' ~--' · ' TELEPHONE NO: Commissioner FROM: Harold R. Hawkins ~'-~?:' SUBJECT: Petroleum Inspector ,~if~ Witness BOPE Test on ARCO Alaska, Inc., Well No. 2D-5, KRU, Sec. 23, TllN,R9E,UM, Permit No. 84-126. Wednesday,_September 12, 1984_: I left Well No. 2G-11, subject of another report, to ARCO's Well No. 2D-5, to witness a BOPE test. i witnessed the BOPE test on ARCO's 2D-5 YdtU Well. There were no failures. I also checked the mud systems controls. I filled out an AOGCC report which is attached. In summary, I witnessed the BOPE test and checked the mud systems controls on 2D-5. Both the BOPE and mud system controls were tested satisfactorily. Attachment 02-O01A(Rev. 10/79) Q&G ~4 5184- Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Well Operator A~ L~'~ Well D--+ General Housekeeping f ]: Reserve Pit ~ ~ Mud Systems Visual Trip Tank Pit .Gauge ~ Flow Monitor / Gas Detectors BOPE Stack Annular Preventer Pipe Rams Choke Line Valves H. C.R. Valve Kill Line Valves Check Valve Test Results: Failures : Location: Sec ~ .% T//~/ R ~Ac ~ M Drillin~ Contractor ~/~/~/f~A° Ri~ Location, General ~/~ Well Sign ... Rig Audio Test Pressure Representative ~?~Casing Set @ .~% ft. Representative ACCUMULATOR SYSTEM Full Charge Pressure psig~~' Pressure After Closure ~ /~~ psig Pump incr. clos. pres. 200 psig ~- Full Charge Pressure'Attained: ~ Controls: Master ~y Remote ~/~ Blinds switch cover min{M~ sec. min~j sec. Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Choke Manifold NO. Valves / F No. flanges ~ Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure Adjustable Chokes Hydrauically operated choke Test Time ~ hrs. Repair or Replacement of failed equipment to be made within Commission office notified. Remarks: · / days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector August 9, 1984 Mr. J. B. Kewin~ Area Drilling-Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 2D-5 ARCO Alaska, inc. Permit No. 84-126 Sur. Loc. 168'FSL, 550'FEL, Sec. 23, TllN, R9E, Btmhole Loc. I!09'FNL, !424'F~%, Sec. 24, TllN, R9E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above rezere~ced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important.for the spa~%ing or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Jeffrey B. Kewin Kuparuk River b%nit 2D-5 August 9, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ve~y~.truly ~v~0urs, ~aiman o f Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COP~ISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location 2D Pad - Wells 5-12 Plat Dear Elaine' EnClosed is an as-built location plat for the If you have any questions, please call me at Sincerely, Gruber Associate Engineer JG/tw GRUB/L24 Enclosure subject wells. 263-4944. RECEIVED JUL l 1 1984 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldC°mpany CONDUCTORS DRILL SITE Z-D AS 'BUILT LOCATIONS F=,5~954.367.I02 Ia.=. 70°3,-7' £I .0458' X- 529,214.1642 Long. t~°45'48.797- 168 FSL 550 FEL EL. 88.8' .O.G. ~LL 6 ~,954,323.0&9 ~. 70017 'i0 ~ S29,254.7648 ~ng. i4~45'47.618" 124 ~L 510 FEL SL. 88.7' O. ~LL 7 ~5,~54,279.047 ~. 70°i7'10.1766' X- ~29,295.2738 ~ng. 14~45'46.443" ~ ~ 470 ~EL ~. 88.6' O.G. 79.3' ~'5,9~,2~.8~4 ~t. 700i 7 '09. 7407' ~ 5~,3~.9398 ~n~. I4~45'45.263" ~ ~ 429 FEL =L. 88.5' O.G. 79. WELL 9 · F-5,~55,830.605 Lat. 70°17 '05. 7498" ;~ 529,708.4131 Long. 149°45'34.458" 3'/0 F~L 59 FE~ ~L. 89.0' O.G. 83.9' W~LL 10 Y~5,953,786 .475 LaC. 70°17'05.3i43' X- 529,749.0452 Long. I49°45'33.279~ 414 FNL 18 FEL EL. 89.0' O.G. ~3.!' ~LL 11 , ~-5,9~3,7~.418 ~, 7~17 04.8793 ~ 529,789.6305 ~ng. !4~ 45'32.102" 4~8 ~L 22 ~L fL. 89.0' O.G. 83.3' . ~LL 12 .183 La= 7~17'04 X~ 529,~.3077 ~ng. i4~45'30.922' ~ ~L 63 ~L ~L. ~.i' Q.G. 83.3' ~. OF AC 9.~.%. ' · Comm~ssb ~ $;aJ CERTIFY THAT I AM PRO~Y REGISTE~D ~ ~~ICE LAND SURVEYIN~ IN THE ALASKA & TI-tAT THIS PLAT REPRESENTS A SURVEY MADE UNDEI~ MY ~~ 3U~RV~SION B THAT ALL DETAILS ARE toska, I'nc, Kup~ru~ ~oject Nort~ DRILL ~NDUCTOR AS. BUILT ~ATfONS ARCO Alaska, Inc. ~-"'-- Post Office B. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 18, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2D-5 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2D-5, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and descriPtion of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on September 5, earliest approval will be appreciated. 1984, your If you have any questions, Sincerely, ~ ewl ~ r i~g Enginee JBK/JG/tw GRU8/L60 Attachments please call me at 263-4970. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED JUL 2 5 I, 114 Alaska 0il & Gas Cons. Commission Anchorage f--" STATE OF ALASKA ~'~ ALASKA O~L AND GAS CONSERVATION COIv, MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL I~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 168' FSL, 550' FEL, Sec.23, T11N, RgE, UN At top of proposed producing interval 1409' FNL, 1276' FWL, Sec, 24, T11N, RgE, UM At total depth 1109' FNL, 1424' FWL, Sec, 24, T11N, RgE, UM 9. Unit or lease name Kuparuk River Unit 10. Well number 2D-5 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 126', PAD 89' ADL 25658 ALK 2584 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide " Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi, NW of De:adhorse miles 1109' @ TD feet 2D-~el160' @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7898' MD, 6:~7~' TVD feet 2560 09/05/84 19. If deviated (see 20 AAC 25.050) I2o. Anticipated pressures 2809 psig@ 80°F Surface KICK OFF POINT 500' feet. MAXIMUM HOLE ANGLE 41 oI (see 20 AAC 25.035 (c) (2) psig@_6122 .ft. TD (TVD) 3153 21 i Proposed Casing, Liner and Cementing Program ~ SIZE SETTING DEPTH QUANTITY OF CEMENT Hole i24~ '12-1/4" Casing 16" 9-5/8" Weight 62.5# 36.0# 8-1/2" 7" 26.0# CASING AND LINER Lengths0 HF-ERW J J-55 J BTC/ 7863 I / MD TOP TVD 36' I 36' 36' I 36' I 35' I 35' I MD BOTTOM TVD 116~ 116' 3726~I 3146' 7898'1 6272' I I (include stage data) ± 200 cf 1075 sx AS III & 685 sx Class G 400 sx Class G neat 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a KuParuk River Field development well to approximately 7898' MD (6272' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3726' MD, (3146' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular), Expected maximum surface pressure is 2809 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, using the workover rig, with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) · 23. I hereby ce~ that the foregoing is true and correct to the best of my knowledge SIGNED////~ ~ TITLE Area Drilling Engineer The spac w mission use . CONDITIONS OF APPROVAL DATE Samples required []YES ~NO Permit number APPROVED BY GRO~/FD28 Mud Icg required Directional Survey required APl number I~]YES I~NO J~YES []NO 50-- O '?..~ Approval date /"'~g,~J'0?~/8~ SEE COVER LETTER FOR OTHER REQUIREMENTS ~a~~~ by order of the Commission 0 Form 10401 Submit in triplicate PERMIT TO DRILL 2D-5 installed and tested upon completion of the job. 2D-5 will be the 8th well drilled on the pad. It is 60' away from 2D-6 at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 6394'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED jUL2 5 1.98 Alaska Oil & Gas Cons. commission Anchorage ~00 ,[ ) _ IA~NLILAR PRE'VENTEi~ g BLIND CSG HD 2 DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK i. 2. 3. 4. , . 16" - 2000 psi Tanked starting head 11" - 3000 psi casing head 1I" - 3000 psi x 13-5/8" - 5000 psi spacer s~ool 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 13-5/8' - 5000 psi pipe rams 13-5/8" - 5000 psi drilling spool w/choke and kill lines - 13-578" - 5000 psi pipe rams 13-5/8" - 5000 psi blind rams 13-5/B" - 5000 psi annular 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 NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI Ri~MAINING PRESSURE. . 10. 11. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL, 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETR.ACT- -"~-- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHE.aJ). RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVEN~FER AND V~LV~S Ul)S~ OF C~-IC)~S. DON~T TEST AGAINST CLOSED CHOKES. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 ~. ~.~'PRESSURE DOWNSK]tEAM OF CHOKE ISOLATION V~LL.¥rJ~S~ TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREJkM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. OPEN TOP S~ OF PIPE RAJAS AND CLOSE BO1-FOM SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. OPEN BOt'FOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND P~AMS'AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM CDMPLE'~E BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPEP~ATE BOPE DAILY. RECEIVED JUL 2 5 IgS Alaska Oil & Gas Cons. Commission Anchoraoe 7 1. 2. 3. 4. 5. 6. 7. Surface Diverter System 16"-2000 psi Tankco starting head. Tankco quick Connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/lC" side outlets. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. i i i i 1 Maintenance & Operation 1. Upon initial installation close annular preventer and verify ~hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEIVED JUL 2 5 ].984 Alaska Oil & Gas Cons. Commission Anchorage CHECK LIST FOR NEW WELL PERMITS ~ ' ~': '~ ~1~ ' ::' : i'T ~i APPROVE DATE (1) Fee (2) Loc thru 8) (3) Admin(9 thru 11) · (10 and 11) (4) /./,.p// '(12 thru 20) Company ~ " (21 thru 24) 1. Is the permit fee attached .., ................................... · 2. Is well to be-located in a defined pool ...... ~ .................. 3~ Is well located proper distance from property line ............ ' . 4. Is well located proper distance from other wells ~ ............. . 5. Is sufficient undedicated acreage available in this pool ...... 6. Is well to be deviated and is well bore plat included ......... 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait ........................ (6) Add: e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. YES Does operator have a bond in force .................................. ~zu~. Is a conservation order needed ...................................... ~-~ Is administrative approval needed ...................................... ~--,_ Is conductor string provided ......... , ............................ Is enough cement used to circulate on conductor and surface . i Will cement tie in surface and intermediate or production Strings .. Will cement cover all known productive horizons ..................... Will surface casing Protect fresh water zones ............... ~. Will all casing give'adequate Safety in Collapse~ 'te~si~ and ~ur~t. Is this well to be kicked off from an existing wellbore .... - ........ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ................ ....... '... ~ NO REMARKS Is a diverter system required ..... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to 3, ~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional r~quirements ............................................. Additional Remarks: 25. .J4 Td O ~-] HO Geology.: Enin~: HWK R LCS WVA~ JKT rev: '12/08/83 6.CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. · ** TAPE tqEAOER ** SERVICE 1.',. A a ,~: :EDIT DAT. E : 8A/.!.0t 12 ORIGIk, :000 PREV1F)bS TAPF, *,* FIL~ HEADER SERVICE ~A~4~', D A T E MAX [ FI' I,,,, f,,, TYPE : PREV It::t~8 O()u 0()0 o 1 b Ubb go0 0:00 : 004 (,6~ 0 0 0 0 0 0 (,) 0 8 (5, 65 0 6,5 o 65 :: / ::.' :0:00 000 002:06.5 : :: 000 0o0 0 1 2 0o5 : 000 006 065 000 003 0~5 T A P !::'. 0 E~.: ,., 'l T Y = ft. 0 0 ~'i ? 1 B (.)T '.['O ~v. I.., i] (; T ht '.r F, ;~ V ,,~, I, = 7962 F' T. Tr~P LOG I~TERVA. L = 3836 FT, CgS]... NG-I. [~(;(;t?,i< = 9,625. '15~, fa. 3836 [;"T. Bi'I SIZE DENSIT~ = 9'80 v '[ S C ~ ~ s ,[ '.i' 'g = ,5. 3.0 t',) 8.50 9.60 9. 460 {~ 64 F 5.152 {a !13 F DATA Fr)RF:~,AT R.KCt)au ~* ('YF'r_i ~IZF. REP? CODE ['Z]k'l'i'~ ~ 2 1, 6b 0 4 1 ~6 8 4 73 60 9 4 65 . i 1 ~'~ 16 1 66 1 () 1 66 ,,.~ r L, S t:.: C J; ~' 1 CJt '.[' l o i'4 t-.) L l. ~. t<..,. t~INEi~ SERtI[.CE Skf, VICE bN'I A, PI ?tPI API AP:I FIbE :SIZE SPL fiEPR t,OG TYPE CI~.55 :'aUD h,O, CODE FT O0 000 O0 :: O: 0 <~: I :68 00000000000000 () }.t rr~ ~ ,,, <'} (.) 220 03, 0 0 4~, I 68 00 o 000 () 0000000 []HN:~: 00: :l/~O ~:" 46.: :0 ': O: 4: O000000000UO0:O 0 :.~ ~,t ~,~ 0 (> 1 2 t~ 44 0 0 ,~i I 68 000 u 0000 {') 00000 ~V 00: '010'. 0'1 4::: I 6~ 000000:0000:0(~00 Gi,~P.[: ~0 3~0' Ol 4 1 6E~ ooOt) OOO0OOOO00 (;;APl O0:3i()' ~Ol', :0 ~ :]::::'0 · 4 I :68 000()00:00000000 ! ~ 0 () 28 O' 0 l, 0 0 4 :1 68 000 o t) 000 o Oo o 00 G/C3:)0 :.3:5'0 ,::"'0:2:.:.:0:: O: :: 1 ': 68 000:00:0:0:000:0000: c;/C23 ()o 356 o'1. () 0 4 1 68 ~:: :68:0'0000:000000000 1 b ~ () (.) 0 0 0 (') 0 0 () 0 0 0 (} 0 ~;'{,:,J O0: 890.:' :00:,:,':<0::,:, , 0 '~:::':: :I t>8 O00:O:O00OO:O000:O Ci,~S O0 330 3! O 0 4 1 6~ O0000uO()OOOO00 C~$ 0.0 , 330 :: : :: 3.0,: x: o ':: 0 6:8 000:0:0000000000 DEPT 7988.0o00 SF[,~ 3.6 i) 02 i .1,,' D 1.. 8 5 6,4 I b SP R H 08 SP NPHI OEP'i' SP RHOB NPiqI DEPT SP NPHI DEPT SP DEPT SP R H O b N P H i DEPT RHOB DEPT SP RH(]B NPH'[ DEPT SP RHOP~ b~PH I D E P T SP N p H I DEPT SP R, H 0 NPHI 2.2734 D R H 0 47.2656 {'ti' C ~,,: L 7800. 0000 SFL, U -3u.6563 1.8301 D R }'"~ 44.1406 :qCb. b 77(.0.000{~ -31.5625 34.1797 NCN[, 79.3 ! 25 G P, O. 1:035 i~RAT 2072,0 t.l u 0 [" C ,",~ I. 79.3125 C: A [., I 3.7227 R N R A 528. 3.9238 2.9023 I. LD 86.8750 GR O. 1 ()01 NiqA 1.679.0000 FCi~L 2.4453 86.8750 436.0()00 2.6836 12.1094 3, ~ 4.. 96 3.7734 ILD 74:.6250 GR -0.0015 NRAT 1687, O00o FCi'q i,~ 3.1973 ILA 74,6250 (tALl 3,7949 RNRA 413.5000 3.5938 13.I406 ,t.0781 6,933b 55.2813 GR 0,0303 ~,ikA:r' 2750.0000 FC.NL 7,1680 IBX 55,281.3 CALl 3,031~ ~i'iRA 875,0000 1.9'~ e 8.7891 3.~426 4.3672 8~,625( Cai'.,:[ 3,;31..8~ RNRA 4.6328 9.1719 3.5957 i ,. 343B 3.3027 2. 6660 11, ! 7i9 4 ~t 36'1 67 a ] ir., I I 6055 ::l: 6 1 3 7: SO: - 0 0 15 ¢', R .A T 3,8535 R ~ R A 4.1, 'i 5 tl ~ :FC::N:L : '159:::'a0:00: 3,8:926 1 .t. 21%,'; 7 -9:99. 2500: DEPT SP N P t{ I DEPT RHO~ NPHI DEPT SP R H 06 NPH I DEPT $ P RHOB O E: P T SP R H 0 [5 NpH'I DEPT SP R H 0 B D E P T $P R Fi 0 B NPI41 D E P T SP RH06 NpH 1 DEPT SP DEPT SP R H 0 ~,~ N P H 1 OEPT SP R H 0 f~ 5800.0000 -39. 590<,' - 999.2500 -999,2500 -54.5000 GR -999.2500 -999.2500 6600. O00O SFI,U - 53.2.'. l ~ 7 G R -999. 2500 DRHO -999,250(; MCNb -38.5000 GR -999. 2500 ,~CNL 5,4259 It.~D 2.9531 101.5525 GR i. 01.5625 -999.250~? i',~Al' -999.2500 -999.2500 FCNL -999.2500 2.7266 ILO 2.9043 :121.. 8'150 Gt.;: !21.8750 -999.2:.300 NR. AT -999. 2500 -999,2500 ~'Ci~:!.,, -999,2500 3.627 (;' ,!: I.., D 3.5430 111.7500 (;R 111.7500 -999,2500 ~',: (~ A ,I.' -999,2500 -999. 2500 [f"CNL -999. 250(7) 3.3730 i6D 3.2695 129.6250 Gk 129.0250 -999,2500 NRAT -999,2500 -999.250(.! FCNi,, -999.2500 ::: :: :3::i t. 04. '9:9:9, - 9 9'9 ~ 3 · :7 O: C A [,, .I C A L J I LN (7 A L i I. 1... fi C .Al.., I (,:A L 17 RNRA I. L CA L, l C A !.,~ I 2~.00 :::NRA'T:':: 2506 ~'C ~', L - 999 87 '1 u I' 1., D 3 ~ 625 :: 2 % t ~ () ' :": ' ' c:90':2 2500. :'FC~.b 3,3594 10.1094 -999,250(? 3.0859 ,t 1,1172 -999.25 ' ' 3.6895 12.2891 -999.2500 3.43'15 12.4375 -999.2500 1.3691 9,6563 -999.2500 2.9531 -999,2500 -999 ~2500 -q99 , 3,9297 -999~25o0 -999'2:500 4.0 2 '? 3 -999.2500 D E D 1' 5700,0 t', C, I'.~ $ J:~' !. SP -41. 5000 GR NPHI -999,2500 NCNb DEPT 54f)O. o000 SP R H D -9 . . 2500 NPHI -999.2~0~.) DEPT 8P R H 0 B NPHI DEPT SP RHOB N p H 1 D E P T 8P N P Id 1 DEPT SP R H ,J B 2. 5723 It, D 2.5684 93. {'., ~ 25 (.; ,~ - 999,2500 -999. 2500 NRAT -999. 2500 -999.250(} FCNL, -999.250o 1L~ 2.74~,2 C,4).,.t. -999,2500 R ~,I R A - 999.250 0 2. '7266 I ii,, I:) 2.79 .atq 95.,t. 375 GR -999;2500 -999. 250,? ~RA'I: -999,2500 999 25L0 FCNL -999 2500 CALl -999. 2500 R ~iRA -999. 2500 2.73~3 IbD 2.5777 85,(.}(~5 G.R -999 2500 -999. 2500 NRAT -999. 2500 Ib~i 2. 8437 c~gI -999. 2500 Rh!RA -999. 2500 2,a.355 lbu , 2,4805 90.68'75 GR 99922500 -999.2560 NEAT -9oc~. .~ ,,, ') ~'; 0 0,.. .., ~ ~.. f.) . '999-,a0. FCNL -999,2500 5801 2500 25 (} 0 I 1, a 2.6 055 CALI -999,250t~ R i<! R A - 999.2500 2.3 6 7 2 l:I t.,~ o 2. a: 3 ~ 5 : ?:6:,:9.3'75 :' (;R.' ::,::::: ':, :"'999',',;;;'256'0 2,!il 33 - 999; 25 00 -999.25(. t) 3. 066,~ -999,2500 - 999 ' 2500 3.5332 '999,2500 -999. 250f.n : :. :,,,9:99:~,',2,,,5:00:: :CALl , 999,:',2.;:50:0 · -999,2500 R~',,iRA -999.2500 ,:1 :: ):' 99'9';',,2:50:0 4,8:,:81 -999,2500 -9:99. 2500 L? I~ III li1 iI~4 ii! [~4 J f~ [,'. Ft I - 999,250 .','~ {'4 C t'.,,f b 6,23~-}3 i t ';, 6,5391 I b 62.37 50 GR -999. 2500 CALl -999,250 o ~',~R~T -999,2500 R~.iRA -999 2500 EC.~ L 999.2500 2.7754 I6D 3.0859 1,1 '1.5f'~O0 GE -999. 250u CALI -999.2500 ~RAT -999,2500 RiqRA -999 ,, 2500 FCc4!., -999. DEPT 4500.000u, SF'Lu SP -75. 5000 GR NPH1 -999.2500 l~ ClXi I,, 3.4-531 96, O00C, Ga -999 -999. 250o NRAT 999. 2500 RNRA - 9 q 9.25 00 DEPT 4:300.t}000 5FLd SP -79.3750 GR NPHI -999,250U 8 ,,3!,25 Ga -999. 250(.) : ."99'9 -999.25t>u FC~I '999. 2500 1: L fyi, C A L, I R l",t R A D E: P T SP DEPT SP RMOB N p H I b.'t344 -999.2500 -999.2500 3.1.660 -999.250L~ -999.2500 1,~ -999,2500 -999,2500 ,l. 082() -99W, -999 , 2500 3,1'i52 -999.2500 -999.250o 3. 630.9 ..,99, :999':2,500 '999':2:5~0: -9,99. 2500 -999. 2500 o09 · [! 00 o 999. 99:9. 2500 DATE ORIGIN :0000 CONT I:~:;ljgT I ON NEXT TA~E CDM~4ENTS :
