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Home My WebLink About182-115CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF1 & CPF3 Subject:1H PAD Witnessed and non witnessed 10-426 forms from 8-22-25 Date:Saturday, August 23, 2025 9:15:03 AM Attachments:image001.png MIT KRU 1H PAD 08-22-25.xlsx MIT KRU 1H PAD SI TESTS 08-22-25.xlsx Good Morning, Please see the attached 10-426 forms from the witnessed and non witnessed shut in MITIA’s that were conducted on 8-22-25. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58+ 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821150 Type Inj N Tubing 960 970 970 970 Type Test P Packer TVD 6205 BBL Pump 1.7 IA 290 2020 1930 1920 Interval 4 Test psi 1551 BBL Return 1.7 OA 5 5 5 5 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1930290 Type Inj N Tubing 2725 2725 2725 2725 Type Test P Packer TVD 6468 BBL Pump 1.7 IA 1030 2020 1960 1950 Interval 4 Test psi 1617 BBL Return 1.4 OA 400 510 510 510 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1930440 Type Inj N Tubing 280 2030 2010 2010 Type Test P Packer TVD 6085 BBL Pump 1.9 IA 220 2030 2000 1990 Interval 4 Test psi 1521 BBL Return 1.8 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: 1H-12 Notes:CMIT T x IA. Open pocket at 7921' Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1H Pad Arend 08/22/25 Notes: Notes: Notes: Notes: 1H-03 1H-09 Form 10-426 (Revised 01/2017)2025-0822_MIT_KRU_1H-03 9 9 9 9 9 99 9 99 9 9 -5HJJ 1H-03 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 4, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IH -03 KUPARUK RIV UNIT 1H-03 Sre: Inspector Reviewed By,: �� P.I. Supryyplz— Comm Well Name KUPARUK RIV UNIT 1H-03 .. API Well Number 50-029-20792-00-00 Inspector Name: Bob Noble Permit Number: 182-115-0 Inspection Date: 8/1/2021 ✓ Insp Num: mitRCN210802090739 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Ix -o3 Type Inj w TVD 6zos Tubing 1060 1060 - 1060 - 1060 - -- 2740 PTD 1821150 Type Test SPT Test psi!7551 - - IA 1365 2210 _ 2150 _ BBL Pumped: 0.8 iBBL Returned: 0.8 OA 120 120- 120 120 Interval 4YRTST P/F P Notes: Wednesday, August 4, 2021 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,August 27,2013 TO: Jim Rper �,�1 ZC� (3 SUBJECT: Mechanical Integrity Tests P.I.Supervisor ((( CONOCOPHILLIPS ALASKA INC 1 H-03 FROM: Jeff Jones KUPARUK RIV UNIT 1H-03 Petroleum Inspector Src: Inspector Reviewed By, P.I.Suprv -- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H-03 API Well Number 50-029-20792-00-00 Inspector Name: Jeff Jones Permit Number: 182-115-0 Inspection Date: 8/11/2013 Insp Num: mitJJ130822142723 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min � Well 111-03 'Type'Ili N "TVD 6205 _ IA �_-52o 1 2800 'I 2670 .' 2645 —_-_ 4 T PTD 1821150 Type Test SPT Test psi 1551 • OA j 100 290 " 300 300 • Interval 4YRTST P/F P ' Tubing 700 700 ' 700 700 J Notes: 2 BBLS diesel pumped. 1 well house inspected,no exceptions noted. • SOWED UEC I 0 ?013 Tuesday,August 27,2013 Page 1 of 1 • MEMORANDUM To: Jim Regg P.I. Supervisor FROM: $ob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 17, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 H-03 KUPARUK RN iJNIT 1H-03 Src: Inspector NON-CONFIDENTIAL ~.J Reviewed By: P.I. Suprv _ Comm Well Name: KUPARUK RIV [JNIT 1H-03 API Well Number: 50-029-20792-00-00 Inspector Name: Bob Noble Insp Num: mitRCN090815092849 Permit Number: 182-115-0 ~ Inspection Date: 8~14/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~,e~~ 1H-03 Type Inj. ~' TVD 6zos ./ IA sso zaao ~ 2a~o zs~o P.T.D is2iiso iTypeTest SPT Test psi Z880 '~ 0.~ 210 350 350 350 Interval 4YRTST P~` r Tubing 2300 2350 2350 2350 Notes: ~~~ . ~'e/~ -~' P~SSc,~ l,s~ ~ Ps~ i ' ,,~ , . ~ ~r,~: a~ t. ;, ~ " ._ ' ~ ~~>~ ~M ~~~ Monday, August 17, 2009 Page 1 of 1 • ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • JUN 1 1 2009 Alaska Oif Gas Cons. Commissiae~ Anchora~a June 9, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 , ~~;'~,,~ ~~t~~, , ; W ~ n rt Dear Mr. Maunder: g~,`) /~' 1 ~'~ 3 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 May 27~', 2009. The corrosion inhibitor/sealant was pumped May 31St and June 1St, 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, MJ Loveland 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 6/9/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 A-06 181-116 n/a 0.25 22" 5/27/2009 1.70 5/31 /2009 1 C-08 181-052 9`6" 3.50 20" 5/27/2009 1.30 5/31 /2009 1C-15 198-229 4'10" 1.00 25" 5/27/2009 3.40 5/31/2009 1 D-125A 200-044 4'9" 1.00 10" 5/27/2009 4.50 6/1 /2009 1 H-03 182-115 15' 10" 2.00 24" 5/27/2009 2.60 5/31/2009 Page 1 of 3 Maunder, Thomas E {DOA) From: Regg, James B (DOA) Sent: Monday, February 11, 2008 1:24 PM To: .Maunder, Thomas E (DOA) Subject: RE: KRU 1 H-03 (1$2-115) I don't have any info or basis to take a position other than what is included in the matrix -clear wording in the matrix is a patch in an injector requires sundry approval. That is how the public would read it, and I'm pretty sure that is how the legal system would also read it. If there is an alternative interpretation that has been applied, I suggest we either amend the matrix with the detailed interpretation, or send out some type of guidance bulletin to clarify. This particular instance was included in the "you've been naughty" letter sent to CPAI last week. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Maunder, Thomas E (DOA) Sent: Monday, February 11, 2008 11:54 AM To: NSK Well Integrity Proj Cc: Cawvey, Von; Peirce, John W; NSK Problem Well Supv; Regg, James B (DOA) Subject: RE: KRU IH•03 (182-115) Thanks for the info/clarification MJ. Tom Maunder, PE AOGCC Jr~xR Erom: NSK Well Integrity Proj [mailto:N1878@conocophillips.com~ Sent: Friday, February 08, 2008 6:07 PM To: Maunder, Thomas E (DOA) Cc: Cawvey, Von; Peirce, John W; NSK Problem WeA Supv; Regg, James B (DOA) Subject: RE: KRU 1H-03 (182-115) Tom, It has been our understanding from previous discussions with you that removable patches below the packer did not require a 10-403 because it is a temporary modification (similar to closing a sliding sleeve or adding dummy valves). Only a 10-404 would be required. The attached email from you also states this. Please let me know if you require any additional information or if the AOGCC has changed intent of the previous interpretation of the regulation. MJ Loveland Well Integrity Project Supervisor 9/23/2008 Page 2 of 3 ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Maunder, Thomas E (DOA) Sent: Tuesday, February 05, 2008 8:48 AM To: 'NSK Well Integrity Field Supv' Subject: FW: KRU iH-03 (182-115) Perry, Here is John's response. Could you provide a list of other wells where such a patch might have been done. Thanks, Tom Maunder, PE AOGCC From: Peirce, John W [mailto:John.W.Peirce@canocophillips.com] Sent: Monday, February 04, 2008 1:10 PM To: Maunder, Thomas E (DOA) Subject: RE: KRU 1H-03 (182-115) Tom, I know I've been through this topic before when I inquired in the past about 10-403's being required for tubing patch jobs in injectors or not. For Ann Comm related patch jobs, I know a 10-403 is required before we patch a well, but I've been operating a while now with the understanding that we do not file 10-403's for'Non-Ann Comm' patch installations in injectors. It's been too long for me to recall for sure where I learned this protocol, but my intent is to follow the rules on required Sundry filings. I will call you in the future to check if I should send a 10-403 for any injector well 'Non-Ann Comm' tubing patch installations. Regards, John Peirce Wells Engineer CPAI Drilling & Wells (907)-265-6471 office From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, February 04, 200$ 12:28 PM To: Peirce, John W Cc: Jim Regg Subject: RE: KRU 1H-03 (182-115) John, Looking at the matrix, patching for injectors is in the 403 needed/407 column. There isn't a distinction about above or below the packer. On page 4, under pumping operations, performing such work to modify the profile does not require a sundry but does require the 404. This one appears "on the line". It probably was appropriate to call for an interpretation. Tom Maunder, PE AOGCC 9!23/2008 Page 3 of 3 From: Peirce, John W [mailtaJohn.W.Peirce@conocophiNips.mm) Sent: Monday, February 04, 2008 11:49 AM To: Maunder, Thomas E (DOA) Subject: RE: KRU 1H-03 (182-115) Tom, 1 H-03 was patched below the packer to stop unwanted injection to the C sand through a leaky Permanent Merla Patch. No T x IA communication exists. The patch was run solely to perform an injection profile modification. Based on the post-patch injection response it appears that the well is probably now on A sand only injection. Should I have filed a 10-403 fora 'Non-Ann Comm' tubing patch installation in an injector? Regards, John Peirce CPAI Drilling & Wells (907)-265-6471 office From: aunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov Sent: Mo ay, February 04, 2008 10:00 AM To: NSK We ntegrity Proj; NSK Well Integrity Field Supv; Peir ,John W Cc: Jim Regg; baum, Alan J (lAW) Subject: KRU iH- (182-115) All, I am reviewing the 10-404 r ently It appears that the tubing was tcl 10-403 was requested regarding by the "operations matrix" attached found record that any T x IA comma for this well. It is requested that you researc h submitted ied. We is worK well. h~4e no record that a ~i a service well as required ~1A. We have also not has been reported record this well to ... 1. determine whe x IA communi n was experienced 2. if any notific on was made to the C mission 3. if notificat' was not made, why 4, any pr sure monitoring information (TIO) AI may have rega mg this well The Commis ' n reserves the right to pursue enforcement on is matter. Your reply ould be received by February 13, 2008. Call or sage with any questions. Tom aunder, PE AOGCC 9/23/2008 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 04, 2008 10:00 AM To: 'NSK WeH Integrity Proj'; 'NSK Well Integrity Field Supv; John Peirce (CPAI) Cc: Jim Regg; Birnbaum, Alan J (LAW) Subject: KRU 1H-03 (182-115) All, I am reviewing the 10-404 recently submitted for this well. It appears that the tubing was patched. We have no record that a 10-403 was requested regarding this work on a service well as required by the "operations matrix" attached to CO 261A. We have also not found record that any T x IA communication has been reported for this well. It is requested that you research the record for this well #o ... 1. determine when T x IA communication was experienced 2. if any notification was made to the Commission 3. if notification was not made, why 4. any pressure monitoring informs#ion (TIO) CPAI may have regarding this well The Commission reserves the right to pursue enforcement on this matter. Your reply should be received by February 13, 2008. Call or message with any questions. Tom Maunder, PE AOGCC ~~~~ FHB ~ ~ Z00~ 2/4/2008 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 44, 2008 9:23 AM To: Jim Regg Subject: KRU 1H-03 (182-115) Jim, Do you have any information regarding T x lA communication on the service well? I don't have any emaiis and there isn't much information in the file. CPAI has filed a 10-404 reporting placing a tubing patch. Patching in injectors is an operation that requires a sundry and they did not obtain one. Tom 2/4/2008 STATE OF ALASKA ~ ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS~A~i ~'~ ?008 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^. e! 8 I ~ r D .~h - Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time~Xi~t~`siorf"" ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, Inc. Development ^ Exploratory ^ 182-115 / 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20792-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 83' 1 H-03 8. Property Designation: 10. Field/Pool(s): ADL 25639, ALK 464 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8155' feet true vertical 7130' feet Plugs (measured) Effective Depth measured 7604' feet Junk (measured) 7635' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SUR. CASING 2748' 10-3/4" 2831' 2686' PROD. CASING 8058' 7" 8141' 7119' Pertoration depth: Measured depth: 7184'-7220', 7276'-7305', 7476'-7481', 7490'-7513' true vertical depth: 6344'-6374', 6421'-6445', 6587'-6591', 6599'-6617' Tubing (size, grade, and measured depth) 3.5" x 2-7/8", J-55, 7378' x 7406' MD. Packers &SSSV (type & measured depth) pkr-- BROWN 'HB-1' RETR. ; BROWN '1 B' pkr= 7022' ; 73 81' Camco TRDP-IA-SSA SSSV= 1799' 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 Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 880 ~ -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~' Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ ~ WDSPL^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none contact John Peirce Printed Name John Peirce Title Wells Group Engineer Signature ~ ,--- Phone: 265-6417 Date ~"Z$"~S ~ P ar b Sb r n AIIs Dr ke 263-461 Form 10-404 Revised 0 /2006 ~ ~ ~ ~ ~~~ i ~=~' tt ~ ~~0~ ~~~ ~~~ Subm~ ~ T r((' • 1 H-03 Well Events Summary DATE Summary '" 1/17108 SET TWO RUN TTS EXPANDABLE TUBING PATCH: 7262' - 7313', TOP ELEMENT: 7264.5', MIDDLE ELEMENT: 7289', BOTTOM ELEMENT: 7312', PULLED 500# OVER TO ENSURE LATCH WITH TOP ASSEMBLY, PUMP TRUCK TO FOLLOW UP JOB TO PUMP UP INFLATABLE PACKER AT 7312' PUMP TRUCK PUMPED UP LOWER EXPANDABLE PACKER AND SHEARED LOWER PUMP OUT PLUG. . . RECEIVED . . 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate [0 ...- Other U ~ Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Ope rat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska. Inc. Development D Exploratory D 182-115/.... 3. Address: Stratigraphic D Service [0 / 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20792-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 83' 1 H-03 8. Property Designation: 10. Field/Pool(s): ADL 25639,'ALK 464 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8155' , feet true vertical 7130' feet Plugs (measured) Effective Depth measured 7610' feet Junk (measured) 7635' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SUR. CASING 2748' 10-3/4" 2831' 2686' PROD. CASING 8058' 7" 8141' 7119' Perforation depth: Measured depth: 7184'-7220',7276'-7305',7476'-7481',7490'-7513' true vertical depth: 6344'-6374',6421'-6445',6587'-6591',6599'-6617' 5CANNED AUG 0 32007 Tubing (size, grade, and measured depth) 3.5" x 2-7/8", J-55, 7478' x 7406' MD. Packers & SSSV (type & measured depth) pkr= BROWN 'HB-1' RETR.; BROWN'1B' pkr= 7022'; 7381' Cameo TRDP-1A-SSA SSSV= 1799' 12. Stimulation or cement squeeze summary: .... Intervals treated (measured) HPBD R8DMS 8FL AUG 0 1 2DD7,00 bbls seawater Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation 367 -- Subsequent to operation 2400 " -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory D Development D Service [0 Daily Report of Well Operations _X 16. Well Status after work: OilD GasD WAGD GINJD WINJ[0 WDSPL D 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: none Contact John Peirce @ 265-6471 Printed Name L~~/~_ Title Wells Group Engineer 7/30/(>7 Signature Phone: 265-6471 Date - PreDared hv Sh"rDn AI/sun-Drake 263-4612 I z;¡ - ¿'b. 7·S(.o7 Form 10-404 Revised 041 06 Submit ri' Only STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONs~laska Oil & Gas Cons. Cammission JUL 3 0 2007 ORIGINAL ~7I71Þ7 . 1 H-03 Well Events Summary . DATE Summary 7/10/07 TAGGED NIPPLE @ 7377' SLM = 18' CORRECTION. RAN 1.75" SAMPLE BAILER. SO @ 7598' RKB. TAPPED DOWN A FEW TIMES, MADE HOLE TO 7604' RKB. 91' OF RATHOLE. BOTTOM PERFS @ 7513' RKB. RECOVFERED FULL SAMPLE BAILER OF SOFT SCHMOO. STAGE OF COMPLETE 7/11/07 Start HPBD using 720 bbl of cold sea-water pumping 9bbl/min. @ 3950 psi pump pressure. ,/' Pumped 200 bbl, shut down, 15 min. readings indicated a 700 psi drop on Tubing Pressure (2500-1700). Second stage, 15 min. Tubing Pressure drop of 825 psi (2550-1725). Third stage, shut down, 15 min. TP drop of 200 psi (2400-2200). During final stage high pressure treating iron failed on one pump, shut down and isolate pump. Complete final stage with 45 min. shut in period indicated a tubing pressure drop of 350 psi (2500-2150). 670 total bbls sea-water away. Using 60/40 methanol, pump 25 bbl, freeze protect and secure well. Rig down, remove fusable cap and hand well over to DSO. . 07/27/07 ScbluJlbel'uel' I'VE NO. 4343 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth dUL ~1 0 2007 5GA..~ AUG 01 20D7 Alaska Oil & Gas Cons. Commission Anchoragø Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 l)Ic"/~J-//S- Field: Kuparuk . Well Job# Log Description Date BL Color CD 1H-08 11850414 INJECTION PROFILE 07/23/07 1 2L-327 11665460 SBHP SURVEY 07/21/07 1 2M-28 11850413 PRODUCTION PROFILE 07/22/07 1 2M-32 11850415 GLS 07/24/07 1 2P-448A 11850403 SBHP SURVEY 07/21/07 1 1H-03 11632739 INJECTION PROFILE 07/23/07 1 2T-37 11632740 PRODUCTION PROFILE 07/24/07 1 2H-14 11632738 PRODUCTION PROFILE 07/22/07 1 . t6 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM TO: Julie Heusser'~'~'~'--,,~[,6'~ Commissioner ~L: v- State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 6, 2001 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~,~,~ ..~ Phillips Alaska Inc. P.I. Supervisor~.~~ 1H Pad .~o\..~\~1::::~1,_ 1H-03, 1H-04, 1H-07, 1H-08, 1H-09 FROM: Jeff Jones KRU Petroleum Inspector Kupamk River Field NON- CONFIDENTIAl. Packer Deplh Pretest Initial 15 Min. 30 Min. ~ 'w,,q '~H-03' if.~,'"'ni.I S I Y-V.[~. i' 'S2~ I'Tua"gl '2500 i 250~'.i 2.500'1 25O6 t~,t,"--q 4:'! p.T.D.I ~82~5o IT~petestl P 'IT--ll 'i~ I.ca..a"gl .~,o. i !e)0..i. ~s~o I .~r,4o I P/F I.P I ..i '.'.we"i. ~"~'.'..i.T.'~'.,n'jJ;i . 'S'.' I' ~.v.0. !. s~a5 I tu~,~ji 2500'! '25a:)'! P:T:D:I ~82~o3o ITYpetestl P ITestpsii..!54~ i Casing.l...900 I.. !77.0 I ~.770, I' ~770 I P/F I Notes: "wad '1H-07 IType~.j.'t "'~' IT.V.D.! 6424 I'Tubingi 2~0' ! '2320"'i" 2320' I 2320 P?-D-.I,~820840 ITypetestl 'P ,'lTeSt,~l !r~' !'~.~i '~ '1 i'7'io I ~74°'1 ,~'.4°, ,I P/FIE W,~q "~H:0S IType~.).! s '1 T-v-b: I ¢~3' t'i'-~.,i ~ I' '~'1 i~ "1 '~ I~ia~! 4 P.I,D..I ao2ma°"'l.'?..~...t..~tl. P.'. '. 'l'i~t.'P~l ..aSs. ~ '"1 ca~l '86o '1". 2aso. ". 'W.~I '~ IiV~,'~.'i" ~s~ I t.v.6, i 0~.~! i'dt~'l 2r;50'1'.' 2sso _ Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER IN J, N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval != Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test'a Detaila Friday~ Jul_v ~ 2001.......~: I traveled to Phillips Alaska Inc.'s IH Pad and witnessed thc 4-year MIT's on wells IH-03, 1H-04, 1H-07, 1H-08 and 1H-09. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with all five wells passing the MIT's. Summary: I witnessed successful 4-year MIT's on PAI's wells 1H-03, IH-04, 1H-07, 1H-08, and 1H-09 in the Kuparuk River Field / KRU. M.I.T.'s performed: _5 Attachments: Number of Failures: O Total Time during tests: 3.5 bm, cc; MIT report form 5/12/00 L.G. MIT 1H Pad pg.2 KRU 7-6-01 JJ.xls 7116/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_ RKB 83 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 791' FNL, 1148' FEL, Sec. 33, T12N, R10E, UM (asp's 549198, 5979910) 1H-03i At top of productive interval 9. Permit number / approval number 987' FSL, 1602' FWL, Sec. 28, T12N, R10E, UM (asp's 546655, 5981672) 182-115 At effective depth 10. APl number 50-029-20792 At total depth 11. Field / Pool 1454' FSL, 1278' FWL, Sec. 28, T12N, R10E, UM (asp's 546326, 5982137) Kuparuk Oil Pool 12. Present well condition summary Totaldepth: measured 8155 feet Plugs (measured) Tagged Fill (2/20/00) @ 7634' MD. true vertical 7130 feet Effective depth: measured 7634 feet Junk (measured) true vertical 6717 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 300 Sx AS II 80' 80' SURF CASING 2748' 10-3/4" 11 00 Sx AS III & 250 Sx 2831' 2686' AS I PROD CASING 8058' 7" 985 Sx G, 250 Sx AS II 8141' 7119' RECEIVED Perforation depth: measured 7184 - 7220'; 7276 - 7305'; 7476 - 7481'; 7490 - 7513' FEB I 6 2001 true vertical 6344 - 6374'; 6421 - 6445'; 6587 - 6591'; 6599 - 6617' Alaska Oil & Gas Cons, Commission Anchorage Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55, Tubing @ 7378' MD; 2-7/8", 6,5#, J-55, Tubing @ 7406' MD. Packers & SSSV (type & measured depth) Brown 'HB-I' Retr. Packer @ 7022' MD; Brown '1B' Packer @ 7381' MD. Camco TRDP-1A-SSA. 2/20/00 - Set 2.81" Frac Sleeve @ 1799' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 350 2400 Subsequent to operation ~ 600 2350 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service __.(Water Inj).~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~. ~~ Title: Date 'Z-/ir ~'/~, Prepared by John Peirce 26,5-64~1,.~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICAT~~ 1H-03i DESCRIPTION OF WORK COMPLETED HIGH PRESSURE BREAKDOWN TREATMENT 2/20100: RIH & tagged fill at 7634' MD. 2/23/00: MIRU & PT equipment. Pumped a Fullbore High Pressure Breakdown treatment through the open perforation intervals located at: 7184 - 7220' MD 7276 - 7305' MD 7476 - 7481' MD 7490 - 7513' MD Pumped Breakdown Scour stage #1 at 23 - 28 bpm, and pumped 2027 lbs of proppant at 1 ppa, followed by Shutdown. ISIP @ 2930. Pumped Scour stage #2 w/rocksalt diverter while pumping away 104 bbls of proppant slurry at 1 ppa. Surged the well back to tanks to flowback wellbore proppant. Reestablished injection after flowing back one tubing volume. Shutdown. Rigged down. Returned the well to water injection & obtained a valid injection rate. RECEIVED FEB 1 6 ; 001 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 19, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate is a Report of Sundry Well Operations (Form 10-404) notice in the Kuparuk field. The well is listed below. WELL ACTION 1H-03 Conversion If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering oCT Oil ,& Ga ,~on~ , -,. ~l~ora~e ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALA;::,,~, OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate ~ Plugging Pull tubing Alter casing Repair well 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 791' FNL, 1148' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 987' FSL, 1602' FWL, Sec. 28, T12N, R10E, UM At effective depth 1396' FSL, 1313' FWL, Sec. 28, T12N, At total depth 1454' FSL, 1278' FWL, Sec. 28, T12NI 12. Present well condition summary Total Depth: measured 8 1 5 5 feet true vertical 7130 feet R10E, UM R10E, UM 6. Datum elevation (DF or KB) RKB 85 7. Unit or Property name Kuparuk River Unit 8. Well number 1 H-03 feet 9. Permit number/approval number 82-115/93-124 10. APl number 50-0;~9-20792 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 8 0 4 5 feet true vertical 7043 feet Junk (measured) Overshot on top of tool string, 44' long, top @ 7341' Casing Length Size Structural Conductor 7 8' 1 6" Surface 2 71 6' 1 0 3/4" Intermediate Production 81 1 4' 7" Liner Perforation depth: measured 7184'-7220' true vertical 6343'-6374' Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 300 Sx AS II 80' 80' 1100 Sx AS III & 2749' 261 3' 250 Sx AS I 985 Sx Class G & 8142' 71 20' 250 Sx AS II , 7276'-7305', 7476'-7481', , 6421'-6445', 6461'-6591', 7490'-7513' 6599'-6618' 3.5", 9.3#/FT., J-55 @ 7378', 2.875", 6.5 #/FT., J-55 @ 7378'-7397' Packers and SSSV (type and measured depth) PKR: Brown HB-1 @ 7022' & Brown lB @ 7381'; SSSV: Camco TI:~P-__IA_w_/_VV_R~Dp_@_ 1799' 13. Stimulation or cement squeeze summary ~ ~, L' [~ ~ V ~ ~ 14. Converted well from oil producer to water injector on 10/15/93. Intervals treated (measured) N/A OCT Treatment description including volumes used and final pressure N/A Alaska 0il & Gas Cons. Commissi.or~ Representative Daily Average production or In!ection Da~al~ch0rage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 642 378 326 1265 175 Subsequent to operation 0 0 2530 900 2270 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service H20 Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~]ned , _ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE PAO.,.E PRODUCTION WELL STATUS -- W Z S E O T CHOKE 7" L N A OR WC H2S CSg L E T % FTP FTT % PPM PSI 10" PSI 0 550 760 470 840 0 350 50 0 500 0 1B PR 176 246 123 55 0 850 2 C PR 176 279 134 55 0 1700 6 B SI 176 258 116 2 25 1400 10 B PR 176 242 94 0 0 430 11 C PR 176 244 88 0 5 1450 13 C SI 0 OM 78 0 0 1500 14 C PR 176 239 60 0 10 1050 15 C SI 0 OM 50 0 0 950 16 B PR 176 243 82 0 5 700 17 B PR 176 235 30 2 5 600 21 C PR 176 248 91 0 0 350 gAS LIFT STATUS IgOR = 30000 SI DAT~ gAS GAS C INJ OPT OPT H M 0 METER VOL RATE gL R I D READINg MSCF MSCFD ROOTS S N E 0 291 188 1. 5 0000 0 0 0 803 4.7 0000 0 0 1307 2006 6.0 1715 82 0 0 0 0.0 0(300 0 0 0 893 ~..'~ 0 0000 0 0 0 0 0.0 2400 63 0 1303 1291 0. 0 0000 0 0 0 0 0.0 2400 63 0 658 607 3. 4 0000 0 0 465 770 4.3 0000 0 0 0 0 0.0 n030 TOTALS' 4024 6558 INJECTION WELL STATUS INdECTION VOLUMES S I DATA W Z S E 0 T CHO~E 7" 10" L N A OR INJ CSg CSg L E T % PSI FTT PSI PSI 4 B PW 176 2256 147 1625 20 '7 B SI 0 OM OM 1520 480 ~ B PW 100 2223 148 560 250 ~ C SI 0 OM OM 980 500 2 C SI 0 OM OM 50~ 0 B C SI 0 OM OM 1200 0 i9 B PW 100 2239 147 760 260 20 C PW 176 2257 146 1160 320 22 C PW 176 2254 146 0 300 WATER RECMD INJ INJ METER VOL RATE READINg BBLS BWPD gAS C INd H M 0 VOL R I D MMSCF S N E 0 413 O* 0.000 5783 0 6561 0 0 0 4307 2633 1430 6804* 0.000 O* 0.000 9871 0.000 O* 0.000 O* 0.000 O* 0.000 3909* 0.000 3337* 0.000 2357* 0.000 0000 0 2400 21 0000 0 2400 33 2400 33 2400 33 0000 0 0000 0 0000 0 TOTALS' SWI' 0 + PWI' 21127 = 21127 26278 0.000 AN * AFTER THE RECOMMENDED WATER !NdECTION RATE INDICATES THAT THE WELL SHOULD BE WIDE OPEN REGARDLESS OF THE LISTED RECOMMENDED RATE, OCT ........... ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 SEPTEMBER 30, 1993 PAUL WHITE ARCO ALASKA INC. P O BOX 100360 ANCHORAGE, ALASKA 99510-0360 re: 82-0115 KUPARUK RIVER UNIT 1H-03 DEAR MR. WHITE, OUR FILES INDICATE THAT ARCO. ALASKA INC. IS THE OPERATOR OF THE MENTIONED WELL IN THIS LETTER. WHILE REVEIWING OUR MONTHLY WELL PRODUCTION FILES I FOUND THE WELL STATUS IS INCORRECT FOR THIS WELL. A 404 SUNDRY WELL OPERATION FORM IS MISSING FROM OUR WELL FILE TO CONVERT THE WELL TO A WATER INJECTOR. AUGUST PRODUCTION REPORTED SOME INJECTION AMOUNT AGAINST THIS WELL. A 403 (SUNDRY APPROVALS) WAS APPROVED TO CONVERT THIS WELL AND OUR FILES DO NOT REFLECT THAT THE WORK WAS ACCOMPLISHED. WOULD YOU PLEASE LOOK INTO THIS'WELL SUNDRY SO WE CAN CLOSE OUT THIS COMPLETED TASK. I AM FORWARDING THIS LETTER AS A RECORD FOR YOU AND ME. THANKS FOR THE QUICK RESPONSE ON THIS REPORT. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN ARCO Alaska, Inc. Post Office Bo'x-~--00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate are multiple Application for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 1 H-03 Cony. to WI June 1993 1H-07 Cony. to WI June 1993 1 H-08 Conv. to WI June 1993 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Engineer Kuparuk Petroleum Engineering Attachments REEEIVED MAY 1 199 Alaska 0il & Gas Cons. Oommiss~O~ gnohorag~ ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C ..... STATE OF ALASKA ALA~:,r,A OIL AND GAS CONSERVATION COMMISo, ON APPLICATION FOR SUNDRY APPROVALS 'd Re enter sus-ended well Abandon_ Suspend _ Operation Shut own _ - p _ Alter casing Repair well Plugging Time extension Stimulate Change approved program ~ Pull tubing _ Variance _ Perforate Other 1. Type of Request: 2. Name of Operator 6. Datum elevation (DF or KB) ARCO Alaska. Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development X_ Exploratory _ Stratigraphic _ Service ' 4. Location of well at surface 791' FNL, 1148' FEL, SEC 33, T12N, R10E, UM At top of productive interval 987' FSL, 1602' FWL, SEC 28, T12N, R10E, UM At effective depth 1396' FSL, 1313' FWL, SEC 28, T12N, R10E, UM At total depth 1454' FSL, 1278" FWL, SEC 28, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Le n gt h Structural Conductor 8 0' Surface 2 784' Intermediate Production Liner Perforation depth: 8108' RKB 85 7. Unit or Property name Kuparuk River Unit \ feet 8. Well number 1H-03 9. Permit number 82-115 10. APl number 50-029-20792 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 8155 7130 8045 7043 size feet feet Plugs (measured) feet Junk (measured) feet Cemented None None Measured depth True vertical depth 1 6" 10-3/4" 7" measured 7184'-7220', 7276'-7305', 7476'-7481', 7490'-7513' true vertical 6343'-6374', 6421 '-6445', 6461 '-6591', 6599'-661 8' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 @ 7378' & 2-7/8, 6.5#, J-55 @ 7378'-7406' Packers and SSSV (type and measured depth) Pkr: Brown HB-1 @ 7022' & Brown lB @ 9706'; SSSV: Camco TRDP-1A-SSSV @ 1799' 300 Sx AS II 80' 80' 1100 SxAS III & 2831' 2686' 250 Sx AS I 985 Sx Class G & 81 4 2' 711 9' ,, R E £ E IV F: D MAY 2 1 199~ Alaska .0il & Gas Cons. C0mrnis,' Anchorage 13. Attachments Description summary of proposal Convert well from oil producer to water injector. 14. Estimated date for commencing operation June, 1993 16. If proposal was verbally approved Name of approver Date approved Detailed operation program BOP sketch 15. Status of well classification as: Oil __ Gas _ Suspended Service Water Injector 17. I hereby certify/~t,~,(~.,~ing is Si~ned (~' (.i). ~ true and correct to the best of my knowledge. Title Engineer FOR COMMISSION USE ONLY Date .~/ZO/~ ~ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_L// Subsequent form require 10-~ IApp~vaLNo. Approved b), order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston Commissioner Date SUBMIT IN TRIPLICATE Attachment 1 ~onversion to Water Injection Kuparuk Well 1H-03 ARCO Alaska requests approval to convert Well 1H-03 from an oil producer to a water injector. This well will be operated as a Olass II UlC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6343' and 6618'. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. Date: January 30, 1989 Transmittal #: 7417 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 B - 0 8 Kuparuk Well Pressure Report I 2 - 0 4 - 8 8 Both Sands 1 B - 0 2 Kuparuk Well Pressure Report I 0 - 2 8 - 8 8 Amerada 1 H- 0 3 Kuparuk Well Pressure Report I 1 - 2 2- 8 8 Amerada I D - 0 8 Kuparuk Well Pressure Report 1 I - 2 5 - 8 8 Both Sands 1 C- 0 4 Kuparuk Well Pressure Report 1-27-89 Amerada Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M State of Alaska Unocal Chevron Mobil SAPC STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMN,,,_,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 791' FNL, 1148' FEL, Sec.33, T12N, RIOE, UH At top of productive interval 987' FSL, 1602' FWL, Sec. 28, T12N, R10E, UM, At effective depth 1190' FSL, 1445' FWL, Sec.28, T12N, RIOE, UM ~t4t~a~' C~¢lth, 1278' FWL, Sec.28, T12N, R10E, UM 5. Datum elevation (DF or KB) RKB 85' 6. Unit or Property name Kuparuk River Unit 7. Well number 1H-3 .... ~ Feet 170 psig 270 psig Dat~6/16/88 Submit in Duplicate ~// 8. Approval number #82-115 ~'-- _,~~ 9. APl number ' 029-20792 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured 7642' MD feet true vertical 6723' TVD feet Effective depth: measured 7642' MD feet true vertical 6723' TVD feet Plugs (measured)None Junk (measured) None Casing Length Size Cemented Measured depth Structural Conductor 78' 16" Surf 78' MD Surface 2831' 10-3/4" Surf 2831' MD Production 8141' 7" Surf 8141' MD xxx~krke~xxxx Perforation depth: measured 7184'-7220', 7276'-7305', 7476'-7481', 7490'-7513' MB True Vertical depth 78' TVD 2686' TVD 7119' TVD true vertical6343,_6374, 6421'-6445' 6461'-6591' 6599'-6618' TVD Tubing (size, grade and measured depth) 3½", J-55, tbg w/Tail ~ 7408' MD BPackers_and S .(t.y~)e .a_nd measured depth) rownHB-1 ~ ~I~ MD; Brown lB @ 7373' MD; Camco TRDP-1A-SSA @ 1791' MD 12. Stimulation or cement squeeze summary 7184' -7220, 7276' -7305' MB Intervals treated (measured) r' t' inclu ' g v m s nd i al ressure Pumped 15 bbls xylene, 45 bbls 3~e~t~ ~¢~~r{er, ~ [~u~ elss~° ~C~ w~lv~rter, & 7 bbls 12% HCl w/o diverter. 13. Hepresen[auve ual~y Average~Proc~uc~on o~'l~njection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 740 BOPD 1280 MCFPD 0 BWPD 1700 psig Subsequent to operation. 940 BOPD 2050 MCFPD 10 BWPD 1400 psiq 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run Ii) 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~ ~,~.,4. <4' Form 10-40'4 R~v. i2-1~'5 Sr. Operations Engineer ARCO Alaska, Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL CONTRACTOR FIELD-DISTRICT-STATE OPERATIONAT REPORT TIME[ . IDAYS 1 DATE F-] CHECK THIS BLOCK IF SUMMARY CONTINUEO ON BACK Weather ITemP'Report °F ChillFact°r IVisibility. °FI milesl wmndv°'' igned ARCO Alaska, Inc. Post Office B~ .. J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Wel 1 Action Anticipated Start Date 2D- !~ 2 ................S ~ .m. U ! ~a.~9 < ~'" 1H-3 Stimulate 1A-2 Stimulate If you have any questions, please call me at 265-6840. Sincerely, May, 1988 lwood Senior Operations Engineer GBS'pg'0181 Attachments cc' File KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtlanltcRichfleldCompany .... STATE OF ALASKA .... ALASK,, OIL AND GAS CONSERVATION COMrv,...,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well FI Alter casing Ii.I Time extension [] Change approved program E] Plugging [] Stimulate ,~ Pull tubing [] Amend order tl;] Perforate I-! Other 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 4. Location of well at surface 99510 791' FNL, 1148' FEL, Sec.33 T12N RIOE UM At top of productive interval ' ' ' 987' FSL, 1602' FWL, Sec. 28, T12N, RIOE, UM At effective depth 1190' FSL, 1445' FWL, Sec.28, T12N, RIOE, UM At total dePth 1454' FSL, 1278' FWL, Sec.28, T12N, RIOE, UM 11. Present well condition summary Total depth: 5. Datum elevation (DF or KB) RKB 85' 6. Unit or Property name Kuparuk River Unit 7. Well number 1H-3 ~o/¢.o-,/,, ~. 8. Permit number Permit #82-115 9. APl number 5O-- 029 -20792 10. Pool KuDaruk River Oil Pool measured 7642' MD feet true vertical 6723' TVD feet Plugs (measured) None feet Effective depth: Casing Structural Conductor Surface Production xx~-k~xxxxx Perforation depth: measured measured 7642' MD feet true vertical 6723' TVD feet Length Size 78' 16" 2831' 10-3/4" Junk (measured) None Cemented Measured d ... True Vertical dep( Surf. 78' MD 78' TVD Surf. 2831' MD 2686' TVD 8141' 7" Surf. 8141' MD 7119' TVD 7184'-7220' MD, 7276'-7305' MD, 7476'-7481' MD, 7490'-7513' MD true vertical 6343'-6374' TVD, 6421'-6445' TVD, 6461'-6591' TVD, 6599'-6618' Tubing (size, grade and measured depth) 3½" J-55 tbg w/tail @ 7408' MD Packers and SSSV (type and measured depth) Brown HB-] Fa 7014' Mn- Rrnwn 1R _Fa 737~' Mn; CAMCO TRDP-!A-SSA @ !79!' ~q) 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation May, 1988 14. If proposal was verbally approved Name of approver Z. "'~ Date approved 15. I hereby.certify that the f~egoing is true and correct to the best of my knowledge Signed '¢/~JC"f~/Z~~"'cd' ~//~/~,.1~.,__~..4.~;jr¢,. ~t.V Title Sr. Operations Engineer Commission Use Only Date 4/27/88 Conditions of approval Form 10-403 Rev 12-1-85 Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ~poroved Copy Returned ,, _ Approval No. Commissioner FVD by order of the commission Date ~/~h SCmit)4~ triplicate WELL 1H-3 General Description Well 1H-3 is an A/C Sand selective single completion. The well is current- ly flowing from both the A Sand and the C Sand. The proposed acid treat- ment would reduce near wellbore damage in the C Sand. The procedure is attached. A coiled tubing unit would be used to administer the treatment. The surface lines would be pressure tested to 4000 psi against the 5000 psi wellhead. The static bottom-hole pressure of the ~ and C Sand combined was measured in August ].987 at 2460 psi. LCF-pg'O071 4 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX KUPARUK WELL 1H-3 ACID STIMULATION ~PROCEDUR£ Pre Stimulation: · , 1. RU slickline. Set blanking plug in "D" nipple at 7386' RKB to isolate A Sand. Replace DVs in mandrel #9 (7052' RKB) and 12/64" CV in mandrel #11 {7345' RKB) with full open CVs to fully open C Sands. 3. RD slickline. 4. Test wel I. 5. Obtain a wellhead fluid sample and perform compatibility testing with 3 percent NHAC1 and 12 percent HC1 (with corrosion inhibitor and mud/silt remover)- Compatibility tests include an emulsion test for 3 percent NH=C1 and an emulsion and sludge test for 12 percent HC1. Except for t~mperature guidelines, the test procedures are the same as those used by Prudhoe Bay {procedures are attached). Use only enough nonemulsifying and antisludging additives as needed to pass the tests. Send a copy .of the test results to Lamont Frazer at ATO/1110. Stimulation: 6. MIRU CTU, nitrogen, and acid equipment. 7. Flush pump company's lines with 3 percent NH4C1 and obtain a fluid sample. 8. Titrate 12 percent HC1. Acceptable concentrations are 10-14 percent HC1. ~ 9. Flush CT with 4 BBLs 12 percent HC1. 10. Pressure test lines to 4000 psi. 11. RIH with CT to 7050' RKB. 12. Circulate diesel in CT/tbg annulus and hook-up a pressure recorder to the annulus. 13. Pump the following at _+2 BPM: 15 bbls xylene 5 bbls 3% NH.C1 20 bbls 3% NH:C1 w/30 lb/lO00 gal diverter "L" 20 bbls 3% NH~C1 w/60 lb/lO00 gal diverter "S" 65 bbls energized 12% HC1 with 80 lb/lO00 gal diverter "S" 12 bbls diesel Notes: 3 % NHmC1 and 12% HC1 are to be filtered with a 2 p nominal filter. AdditiVes for 3% NH~C1 and 12% HC1 are attached. 12% HC1 should be e~ergized with 400 SCF/B. If possible, monitor pressures at CT/tbg annulus. Do not exceed 1800 psi. Fluid samples should be obtained for unfiltered 3% NH~C1 and 12% HC1. Fluid samples should also be taken downstream of the f~ter after every 30 bbls. Clearly label all samples. Diverter concentrations are only estimates. Adjust diverter concen- trations as needed. 14. Displace diesel with nitrogen. 15. Open well immediately. Flow well to tanks while lifting with nitrogen at 500 SCF/Min. 16. Obtain two samples of the spent acid and analyze for ferrous and ferric iron ASAP. 17. Continue to lift with nitrogen at maximum flow rate until 300 BBLS of fluid are recovered. 18. POOH wi th CT. flowing. If necessary, circulate with nitrogen to keep well 19. RD equipment. 20. Test well. Post Stimulation: 21. RU slickline. Pull blanking plug at 7386' RKB to open up A Sand. 22. Analyze 3 percent NH.C1 and 12 percent HC1 samples for particle concen- tration and particle4 size distribution. Also, perform post treatment emulsion and sludge tests on one of the filtered acid samples. Send a copy of all test results to Lamont Frazer at ATO/1110. ARCO Alaska, Inc, Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 11, 1987 Transmittal # 5933 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-16 2T-12A 2A-11 3A-9 lA-1 3A-9 1H-3 3K-13 3K-14 3I-1 3F-15 CET/CEL 9-15-86 8181-8720 CET/CEL 9-27-86 4595-6644 CET/CEL 3-14-86 5800-6564 CET 7-26-86 2000-6299 CEL/CET 8-29-86 2708-7255 CET/CEL (After Squeeze) 7-31-86 2128-6039 CET 7-16-86 6891-7617 CET/CEL 8-17-86 6849-8455 CET/CEL 8-18-86 7215-8844 ' CET/CEL 1-24-86 7588-8887 CET/CEL 1-13-86 6600-7384 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil .SAPC Unocal BPAE · Chevron Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtlanllcRichfleldCompan¥ ~-~'~ STATE OF ALASKA "- ~ ALASK~ OIL AND GAS CONSERVATION L,O~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well -/// OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-115 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 029-20792 4. Location of well at surface 9. Unit or Lease Name 791' FNL, 1148' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Unit 10. Well Number At Top Producing Interval 987' FSL, 1602' FWL, Sec. 28, T12N, R10E, UM 1H-3 At Total Depth 11. Field and Pool 1454' FSE, 1278' FWL, Sec. 28, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB 't ADL 25639 ALK 464 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 7/24/82 8/05/82 08/09/82*I 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 8155'MD, 7130'TVD 7642'MD,6723'TVD YES []XX NO [] 1799 feet MDI 1600' (Approx) 22. Type Electric or Other Logs Run D IL/GR/SP, Cal/GR, DIL/SP/SFL/GR/FDC/CNL, CBL/VDL/CCL/GR, Gyro/CCL, GR/CCL, CET, CST-C 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i 6:~ bZ.b¢~ I-I-~,U Surf 78' 24" 300 sx AS I I 10-3/4" 45.5# K-55 Surf 2831' 13-1/2" 1100 sx AS Ill & 250 sx t~S I 7" 26.0# K-55 Surf 8141' 8-1/2" 985 sx Class G & 250 sx t,S II 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) 7184' - 7220'MD 6343' - 6374'TVD 3-1/2" 7406' 7022' & 7381' 7276' - 7305'MD 12 spf 6421' - 6445'TVD 7476' - 7481 'MD 6461' - 6591'TVD 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7490' - 7513'MD 6599' - 6618'TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See Attached. 27. N/A PRODUCTION TEST ..... Date First Production Method' of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested. PRO.DUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing CaSing Pressure CALCULATED.~, OIL-BBL GASIMCF WATER-BBL OIL GRAVITY-APl (co[r) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of I'ithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None OC'i" 2 0 1986 Alaska Oil & 6as Cor~s. Comrnissior~ Anchora.ge Submit in duplicate Form 10-407 WNote: Well Wa~c~l~_~l~SE~vs~J ~/E2~E/R8¢E SlD~EC1/132 Rev. 7-1-80 NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand Top Ugnu Top Lower Ugnu GEOLOGIC MARKI~RS MEAS. DEPTH TRUE VERT. DEPTH 6343 6447 6579 6673 2525 3089 30. FORMATION TESTS 7183' 7307' 7466' 7581' 2652' 3280' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1H-3 Cont'd Item 26: HYDRAULIC FRACTURE Mix 8 ppg 20/40 frac sand. Tubing 7" Design Actual Sta~ Pressure Pressure Volume Volume 1. Pre Pad 4890 2100 80 2. 100 Mesh 4520 2210 19 3. Pad 4320 2260 70 4. 3 ppg 4140 2490 23 5. 8 ppg 4000 2520 41 6. Flush 4650 2760 65 8O 19 70 24 41 65 Rate 20.1 20 20 19.8 19.3 19.7 End job, begin 15 min. SI Pressure = 2510 ~ 0 minutes " = 2310 ~ 5 minutes " = 2110 ~ 10 minutes " = 1930 ~ 15 minutes Fracture completed ~ 1152 hours, 9/08/86. SUMMARY Hydraulic fracture went per procedure Stage 5, 8 ppg was light by 310 lbs., 9770 vs. 10,080. o Frac gradient = .73 psi/ft WC1/132b:dmr 10-10-86 .... STATE OF ALASKA AL/-.. ;A OIL AND GAS CONSERVATION CO~.,,JISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging Alter Casing [] Other 2. Name of Operator ARCO Alaska~ Inco 3. Address P,0, Box 100360 Anchorage, AK 99510 4. Location of well at surface 791'FNL, 1148'FEL, 5ec.33, T12N, RIOE, UN At top of productive interval 987' FSL, 1602'FWL, Sec.28, T12N, RIOE, UM At effective depth 1190'FSL, 1445'FWL, Sec.28, T12N, RIOE, UM At total depth 1454'FSL, 1278'FWL, Sec.28, T12N, RIOE, UM 5. Datum elevation (DF or KB) RKB 85' 6. Unit or Property name Kuparuk River Unit 7. Well number 1H-3 8. Approval number Permit #82-115 9. APl number 50-- 029-20792 10. Pool Kuparuk River Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 2784' 8113' Production 8155'MD 7130'TVD 7642'MD 6723,TVD feet feet feet feet Plugs (measured) Junk (measured) None Vann Gun Fish ¢ 7642' Size Cemented Measured depth ~ue Vertical depth 16" 300 sx AS II 106'MD 106'TVD 10-3/4" 1100 sx. AS Ill & 2831'MD 2686'TVD 250 sx AS I 7" 985 sx Class G & 8141'MD 7119'TVD 250 sx AS II Perforation depth: measured true vertical 7184'-7220'MD 7276'-7305'MD 6343'-6374'TVD 6421 ' -6445 'TVD Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 7406' Packers and SSSV (type and measured depth) HB-1 pkr ~ 7022', lB pkr ~ 7381', & TRDP-1A-SSA SSSV ~ 1799' 12. Stimulation or cement squeeze summary 7476'-7481'MD 7490'-7513'MD 6461'-6591'TVD 6599'-6618'TVD /A I n%rvals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OilIBbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Recompletion Well History) Daily Report of Well Operations Copies of Logs and Surveys Run E;! 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85~ Title Associate Enqineer (DAM) SW0/084 Date ~-4-~L¢ Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are star~ed. Daily work prior to spudding should be summarize~o_n the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK1070 Pool 102 Operator ARCO Alaska, Inc. Spudded or W,O. begun Workover 7/12/86 thru 7/14/86 JCounty. parish or borough North Slope Borough JLeaseorUnit ADL 25639 JTitle Recompletion Jstate Alaska IWell no, 1H-3 W/O API 50-029-20792 7/15/86 7/16/86 7/17/86 J ARCO W.I. IHour [Prior status if a W.O. 2300 hrs. 56.24% 7/18/86 IDate 7/11/86 Date and depth as of 8:00 a.m. Complete record for each day reported 7" @ 8141' 8045' PBTD, POOH w/tbg 10.0 ppg NaC1/NaBr Accept rig @ 2300 hrs, 7/11/86. Kill well by bullheading 78 bbls 10.0 ppg brine dn tbg. RU SL unit, RIH, pull GLM dummy @ 6972', POOH, RD SL unit. Displ well w/10.0 ppg brine. Circ kill pill to GLM & sqz'd perfs; well not dead. Circ 1 compl hole vol; well dead. Set BPV. ND tree, NU & tst BOPE. Att to shear SBR; would not shear. RU WL unit, RIH, cut tbg w/2½" tbg cutter @ 6988', POOH, RD WL. POOH, std back 3½" tbg. 7" @ 8045' 10.1 POOH left 8141' PBTD, RIH w/SBR retrv'g tl ppg NaC1/NaBr w/3½" tbg. RIH w/OS, latch fsh & jar free, POOH; retrv'd SBR, pkr dn hole. MU SBR retrv'g tl & RIH. 7" @ 8141' 7642' PBTD, MU BP 10.1 ppg NaC1/NaBr TIH w/FTA #2, wrk over fsh, POOH, retrv'd pkr assy. Rn gage ring/JB; unable to get below 7478' WLM, POOH, RD WL unit. RIH w/bit & scrprs to 7642' PBTD, CBU, POOH. RU Schl, rn gage ring/JB to 7625' WLM. Rn CET f/7617'-6891' WLM, RD WL. 7" @ 8141' 7642' PBTD, POOH, LD DP 10.1 ppg NaC1/NaBr RIH, set BP @ 7153', POOH. ND BOPE, chg out tbg head to 5000 psi head. NU & tst BOPE. TIH w/retrv'g tl, catch BP, release same, CBU, POH, LD DP. 7" @ 8141' 7642' PBTD, Lnd tbg 10.1 ppg NaCl/NaBr POOH, LD DP. Set WL pkr @ 7373' WLM. hgr. Rn 3½" CA. Space out The above is correct For fo~n preparation and d str buhon, ~' see Procedures Manual, Section 10, Drilling, Pages 86 and 87, Drilling Supervisor ARCO Oil and Gas Company ,~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish ~State Alaska North Slope Borough Alaska Field Lease or Unit Kuparuk River ADL 25639 -3 W/O Auth. or W.O. no. T t e AFE AK1070 Recomplet ion Pool 102 API 50-029-20792 Operator A.R.Co. ARCO Alaska, Inc. Spudded orWorkoverW'°' begun Date 7/19/86 thru 7/21/86 Date and depth as of 8:00 a.m. Complete record for each day reported W.I. 56.24% 7/21/86 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W.O, I 0600 hrs. 7" @ 8141' 7642' PBTD, RR Diesel Fin rn'g 236 its, 3½", 9.2#, J-55 AB Mod tbg w/SSSV @ 1799', lB Pkr @ 7381', HB-1 pkr @ 7022', TT @ 7406'. Damaged 2 sets of seals before getting hgr lnd'd. Tst ann & pkr; hgr leaked. Shear PBR, POOH w/3½" tbg. PU BP, RIH & set BP @ 6520'. POOH w/3½" DP. ND BOPE, chg out tbg spool, NU & tst BOPE. POOH, LD DP. Re-rn 3½" compl &lnd. RIH w/std'g vlv, tst tbg to 2500 psi. ND BOPE, NU & tst tree. Displ to diesel. Tst orifice vlv; OK. Set BPV. RR @ 0600 hrs, 7/21/86. Old TD Released rig 0600 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data New TD PB Depth 7642' PBTD Date Kind of rig 7/21/86 Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 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 Allowable Effective date corrected The abov~s correct Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ATTACHMENT II Drill Site lA Well No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 lA- 16A KUPARUK RIVER UNIT Productio,,n Logs FEBRUARY 19, 1986 Lo, 9 Date Drill Site Well No. Lo9 Date 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB 1B-1 12/26/81 1B-2 6/25/81 1B-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Dri 11 Si te 1C Well No. 1C-1 1C-2 1C-3 1C-4 1C-5 1C-6 lC-7 1C-8' Log Date 5/9/81 518181 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 1D 1D-1 ~ 1/80 5/23/83 1D-3 8/5/80 1D-4 7/30/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 1D-7 6/8/81 b_~D-8 (ws-8) 51i0/78 Attachment Page 2 Drill Site 1H Drill Site lQ Well No. Lo9 Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Well No. Lo9 Date ~1Q:-5~12/1/85 Drill Site Well No. Lo9 Date 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Lo9 Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. 9/7/82 1F 1F-1 9/25/82 1F-2 9/28/82 1F-3 i2/8/84 1F-4 10/13/82 1F-5 11/12/82 1F-6 3/!2/83 1F-7 ~Jaska Oil & Gas Cons. Log Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attachment . Page 3 Drill Site 1Y Well No. Lo9 Date 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~~ 6 / 18 / 83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~Y~-,'~ll~. 5/10/83 ~.-...~ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 IY-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site 2C Well No. Lo9 Date 2C-4 2/19/85 2/28/85 2C-7 10/15/84 %2C~16~12/1!/85 Drill Site Well No. Lo9 Date 2Z ' ' ~_Z~ 7/10/83 2Z-2 ': 6/24/83 7/19/83 2Z-3 ' 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF' pg' 0052 o Alaska Oil & Gas Cons. Anchorag~ Drill Site 1H Wel 1 No. ""'" 1H-3 "IH-4 1H-7 '"1H-8 Lo9 Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E 1E-lA ~/19/81 1E-2 ~8/17/81~-7 '"'1/17/84// 1E-3 '"'10/18/81'-... , -,..11/7/81// 1E-5 ~10/27/81, 1E-6 ~10/21/81~ ~11/12/82/ ~1E-7 ~/28/81~ ~10/28/81~ 1E-8 ~8/28/81~ ~. ~11/1/81/ 1E-12 ~11/28/84 1E-15 ~8/26/82 1E-16 ~/29/82 1E-17 ~9/1/82 1E-20 ~5/7/83 .1E-24 ~/17/83 1E-25 ~1/17/83 1E-26 ~1/13/83 1E-27 ~0/31/82 1E-28 ~10/27/82 ) ~' ~6/13/83 1E-29 ~10/18/82~ ~ ~7/~8/83/ 1E-30 ~10/16/82 ~-~ Drill Site 1G Wel 1 No. Log Date 9/7/82 '9/25/82k~ 9/28/82 12/8/84/ 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. Log Date 1F '~1F-1 2/19/83 '~1F-2 2/3/83 '""1F-3 1/31/83 '~1F-4 5/29/83 '",,1F-5 10/25/82 '~1F-6 10/28/82 ~ 1F-7 11/19/82~,, ~ 5/7/83 RECEiVI FEB 2 1 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office B~.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 18, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 300! Porcupine Drive Anchorage, AK. 99501 SUBJECT: iH-3 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to convert 1H-3 to a selective single completion. Since we expect to start this work on January 8, 1986, your earliest approval will be appreciated. If you have any questions, please call Jeff Qu{mtana at 263-4620 or myself at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw SN/L084 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COtv~MlSSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLxt~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 791' FNL, 1148' FEL, 5ec.33, T12N, R10E, UH 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 7. Permit No. 82-115 8. APl Number 50- 9. Unit or Lease Name Kupar,_,k River Unit 10. Well Number 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. RKB 85' Am 756_~9 _A_LK 46~ i 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). ARCO Alaska, Inc., proposes to convert well 1H-3 to a selective single completion. The procedure will be as fol 1 ows: 1. Well will be killed with brine. 2. Current completion assembly will be pulled. 3. A cement squeeze will be done to isolate zones. 4. A retrievable packer will be run to test casing. 5. The Cl Sand will be perforated. 6. The well will be completed as a selective single using three packers. 7. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: January 8, 1986 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. <~ ~ ~~1~ Title Associ ate Engi neet Signed The space belCfor Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 (JLQ) SN/122 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ' .',00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-05-85 TRANSMITTAL NO: 5332 RhTURN TO: TRANSMITTED RECEIPT AND SEQUENCE OF ARCO ALASKA, INC. KU PARUK_ OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 HEREWITH ARE THE FOLLOW kETUI~ ONb SIGNED COPY EVENTS PRESSURE DATA iH- 3 -"' PBU 2A-I~-,~ 'C' SAND PBU 2B-l?,-" 'C' SAND PBU 2C-~J 'A' SAND PBU 2V-2 - 'A' SAND PBU 2V-5 ~ 'A' SAND PBU ENGINEERING ING ITEMS. OF THIS 03-07-85 08-03-85 08-01-85 08-16-85 07-27-85 06-25-85 PLEASE ACKNOWLEDGE TRANSMITTAL . SEQ~3ENCE OF EVENTS FROM WELL SERVICE 1A-8-~ bBHP & [qISC. 0 la-5 PBU & MISC. la-3~''~' PBU la-}~' PBU lB-2 .... 'C' SAND PDU lB-2 ....... 'C' SAND PBU 1B-5~~'~ ~TATIC TEMP.LOG 1E-21~ RUN BHP & MISC. REPORT 8-22-85 08-14-85 08-12-~5 08-11-85 08-05-85 O8-06-85 08-15-~5 0~-03-~5 PRESSURE.' DATA 1F-5 .... PBU 1F-5 ~./~ PBU 1G-15-~ 'C ' 1G-15~ 'A' 1G-15~/' 'C'. 1R-10 ....... ~' BHP 1R- 9~w'~ Bit P 1R-12 ~ BHP 2A-1'/ 'C ' 2A-1'/ 'A' 2A-1''~ ' C ' 2A-13 ..... BI/P 2B-13~ 'A' 2B-13 'C' 'A' & 'C' bAND (ISLTD) SAND PBU ~AND PBU & MISC. SAND PBU & MISC. & MISC. & MISC. SAND PBU SAND BHP SAND PBU & MISC. SAND SAND PBU 2B-13 ..... DATA FROM BHP SURVEY 2B-13~ 'C' SAND Pb~3 2C-8 "' PBU 2G-16~' PBb / 2G- 16 / PBU RLCEIPT ACKNOWLEDGED: BPAE D~ILLING B. CURRIER L. JOHNSS?ON CHEV liON bit, t31 L D & M NbK CLEP, K 08-18-55 08-17-85 08-10-85 08-06-85 08-09-85 08-15-85 08-15-85 08-19-85 08-04-85 08-04-85 O8-03-85 08-25-85 08-02-85 08-02-85 08-03-85 08-01-85 08-17-85 08-17-85 08-1~-85 DISTF, IBUTION: W. PAStiER EXXON *PLEASE NOTE--DISTRIB- UTION CONTINUED ON NEXT PAGE. , ,- P~ILLIP~ OIL UNION J. ~%'~qELL K.TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfietdcompany ARCO Alaska, In,'~ Post Offic,_ .~d,~ 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 5296 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLEKK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE DATA ~1C-4 '- 07-23-85 '-~ 1C-5 · 07-29-85 '~ 1C-5 .~ 07-30-85 '~iC- 6 ~ 07-25-85 "'-1C-6 .. 07-24'85 ~lD-8 ~ 07-30-85 -"' 1H- 3, 07-30-85 ---~iR-5- 07-05-85 ~'-lz4- 6 07-06-85 --" 1R-8 07-U~-85 1Y-10- 07-27-85 1Y-11-' 07-28-85 2A-2 ." 07-04-85 2B-13' 07-30-85 2U-14' 06-30-85 2U-14''~ 07-01-85 2U-15 07-08-85 2V-2 07-27-85 2V-2 07-28-85 2W-7- 07-26-85 '~2W-7- 07-27-85 2X-15~ 07-09-85 2X-15" 07-04-85 2Z-l- 07-05-85 ~2Z-6- 04-08-85 '~3B-7--. 06-27-85 3B-8~' 06-28-85 3B-8~ 06-27-85 ~3B-9 / 07-18-85 3B-11 07-20-85 3B-12' 07-21-85 3C-11-" 07-29-85 STATIC BHP PBU PBU STATIC BHP STATIC BHP STATIC BHP STATIC BHP DHP & MISC. BHP & MISC. STATIC BHP & STATIC BHP END OF PBU 'C' SAND STATIC BHP PRESSUkE DATA 'A' SAND PBU 'A' SAND PBU PRESSURE TEST & ~IISC. 'A' SAND PBU 'A' SAND PBU 'A' SAND ONLY PBU 'A' SAND PBU FLOWING BHP & FLUID I.D. FLUWING BHP & TEMPERATURE BHP SURVEY & MISC. STATIC BHP STATIC BHP & MISC. STATIC BHP & MISC. BHP & MISC. STATIC BHP & MISC. BHP SURVEY & MISC. STATIC BHP & MISC. STATIC BHP & MISC. RECEIPT ACKNOWLF. DGED: DPAE* B. CURRIER CHEVRON* D & ~4' DISTRIBUTION: DKILLING W. PASHER L. JOHNSTON EXXON HOBIL* PHILLIPS OIL* NSK CLEkK J. RATRMELL* ' ARCO A~sska. Inc. is a Subsidiary' of AHanticRichfjeldCompany CAMCO DRESSER ATLAS DRESSER ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DRESSER ATLAS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CALICO [! / ...... ,-~o. U0~;ImissJ0rt STATE OF' '~'ASKA* SOHIO* UNION* K · TULIN/VAULT ARCO Alaska. In,~ Post Offic. _;'bx 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TP, ANSMITTAL NU:5292 KETUP~q TO: ARCO aLASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ENGINEERING TRANSMITTED kECEIPT AND KUPARUK ' lB-1. 1B-2~ 05-30-85 ~lB-4. 05-16-85 ~ 1C-4 07-24-85 · 1C-6-~' 07-25-85 - 1D-8-~ .07-30-85 --1H-3 07-30-85 · '- lQ-13~· 06-24-85 '~ lQ- 14-'" 06-23-85 '~iQ- 15' 06-21-85 "lQ-16'" 06-21-85 1R-5'~ 07-05-85 1R-6 '~' 07-06-85 "lR-7/' 07-06-85 -' 1R-8 ~ 07-08-85 "2A- 2- ' 07-04-85 ~2W-7~ 07-26-85 '-2V-3 07-11-85 .~2W- 15' 08-04-85 3B-t - 06-14-85 3B-2~-'" 06-14-85 3B-3'~'' 06-28-~5 "3B-3' 06-15-85 --3B-4- 06-15-85 "3B-5 -'~- 06-26-85 '3B-6''~ 06-26-85 --3B- 7" 06-28-85 3B-7-- 06-27-85 3B-8~ 06-28-85 '-3B-9~ 07-18-85 ~3B- 10-" 07-20-85 -3B-11 -- 07-20-85 3B-12 .... 07-21-85 3B-13. 05-29-85 -'3B-14 05-29-85 RECEIPT ACKNO~LEDGED: HE~E%~ITH ARE THE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. ¥4ELL PRESSURE REPORT--ENVELQPE FACE DATA 05-30-~5 CAMCO '~3B-15 FOLLOWING ITEMS. PLEASE ACKNOWLEDGE CAMCO 3B-16-' CAMCO ~ 3C-11-' CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OTIS DHESSE~ OTIS OTIS ???? CAMCO OTIS CAMCO CAMCO CAMCO CA['JCO CAMCO CA[4CO OTIS CAliCO CAHCO CAMCO CAMCO OTIS OTIS 05-28-85 OTIS 05-28-85 OTIS 07-29-85 CAMCO DISTRIBUTION: BPAE* DRILLING W. PASnER B. CURRIER L. JOHNSTON EXXON CHEVRON* ~,~B IL* PHILLIPS OIL* D & M* NSK CLERK J. RATHMELL* Z6~ STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO .a, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 07-02-35 TRANSMITTAL N0:5237 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-11i 5B P.O. BOX 100360 ANCHORAGE, AK 99510 T RANSM ITT ED RECEIPT AND PRESSURE TEST HER~.,IITH ARE THE RETURN ONE SIGNED FINALS ENGINEERING FOLLOW lNG COPY OF ITEM S Z.-/'PLEASE ACKNOW LEDGE THIS TRANSMITTAL. C AMC 0 lQ-9 PBU 03-30-35./ 1Y-12 FALL-OFF .05-05-85// OTIS 2E-9 STATIC GRADIENT 06-11-85/' ?E-13 STATT~ - ~- GRADIENT 06-10-85'" 2E-1.4 STATIC GRADIENT 06-10-85/ 2E-!5 STATIC GRADIENT 06-09-85z/ 2U-14 PRESSURE BUiLD-UP 06-17-~ 5/ ~U-i6 PRESS - U.~a BUILD-UP 06-06-85/ 2U-16 STATIC GRADIENT 06-13-85/ 2U-!6 PRESSURE BUiLD-UP 0~-i~-85 2t{-12 STATIC GRADIENT 06-08-85/ 38-!3 STATIC GRADIENT 05-29-85/ TORQUE TURN 2C-3 S~'' ~"~ --,~ ~. ;,... TEST 2D-2 24 !IR PBU 03-30/3!-85 04-21/22-85 GAUGE !~63132 ' GAUGE !~63137 / llqq ES Lit=3 PRESSURE BUILD-UP 03-03/04-85 GAUGE ~, 2059 / - - - ~-...- .~.'.,_/,: L ':DCED: D ~ 3UTION .~A,_,:' * Dr-. , r LL "'" ;'"=,,~ W o7~ e · CURi~i2R L. JO:~NS'fON.. EXXC'~ :r"'l]r~""'';~ 'iO"~Tr * PIiiLLiPS OIL* & ,":* NSK Cl.?iRK J. iL?,TIIMELL* ARCO Alz !nc. Post Office Box 100350 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-24-85 TRANSMITTAL NO: 5227 RET URN TO- ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCtlORAGE, AK 99510 F~NSM ITTED RECEIPT AND KUPARUK iB-3\ 04-21-85 PBU BOTH SD. CAMCO 1C-4~ 04-25-55 SG!IP BOTH SD. CAMCO i!!'3~ 03-06'~85 PGU BOTII SD. CAMCO 1Q-i~ 05-26-S5 SBHP 'A' SD. CAMCO 1Q-2~ 05 "6-85 SBHP 'A' SD. CAMCO 1Q-3~ 05-!~-85 SBHP 'A' SD. CAMCO 1Q-4x 05-14-85 SDHP BOTH SD. CAMCO 1Q-5~ 06-06--85 SBHP 'C' SD. CAMCO lQ-6. 04-23-85 SEHP CAMCO 1Q-7~ 04-17-85 SGHP 'A' SD. CAMCO iQ-8-~ 04-03-85 SBHP 'A' SD. CAMCO 2A-2x, 05-'~7-$5~ SBHP 'C' SD. OTIS 2A-4~ 05-11-85 SBIIP 'A' SD. CAMCO 2C-5x 04-23-85 P~U 'A: SD. BAKER NORTH SLOPE 2C-9 '- 04-06-85 SBttP 'A' SD. OTIS 2C-!0\ 04-40-85 SBHP BOTH SD. OTIS 2C-1i~,, 03-29-85 SBHP 'A' SD. OTiS 2C-12x 03-26-35 SBHP 'C' SD. OTIS 2C-14~ 04-23-85 PBU 'A' SD. OTIS & BAKER 2C-!~ 0(-29-85 F~,:P 'A SD. CAMCO oH-1,, 05_o3_$5 ooo'~ oooooooo CAMCO 2H-~_~ 0o-~- '~7-85 SEHP 'A' SD. OTIS ~°!{-2" 05-23-85 oooo..., ooo~,oooo........ CAMCO 21I-3~, 05-23-85 SBII? 'A' SD. OTIS 2!!-4~ 05-23-85 SD!IP 'A' SD. OTIS 2V-9'- 0 5-18-8 5 SEll? lA ' SD. OTIS 2V-!0%. 05-17-85 SBi!P 'A' SD. OTIS ]V_i~ , , ~' - 05-12-85 SBH? A SD. OTIS _~V-!~ 05-i4-~5 SBH? OTIS tX-2-- 06-16-85 SBItP EOTfl SD. OTIS .>X-2'. 06-14-85 oBhP° · BOT~! SD. OTIS ~X-5~ 06-12'85 SDH? BOTIt SD. OTIS ~'~-6~ 04-0S-85 e~-~p ~-7- 04-23-85 PUU EOTiI SD. BAKER NOTH SLOPE ~'Z-2~, 0~-01-$5 SEII? GOTH SD. OTIS .?.~I.~ ACKNOWLEDCED: ?AE* & M* HEREWITH ARE TIiE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. WELL ?RESSURE REPORT ENVELOPE DATA DATE; . STATE'~O~'~, ALASKA* / SOIIIO* UNI .... ARCO Alaska, Ir" Post Office .~ox 360 Anchorage, Alaska 99510 · Telephone 907 277 5637 r"~ '!" 0 .... i i '? .~ iii(',' ?, '".)., ):')~ !D X 'i 0 0 7,";':, '7:' -, ,":'.~ ?.! C: !"i (:)F;~ d:i (:; Iii:, ¢'; !-':: · ':? '7' ?: ! ";"::, ,-.., ....... ,,-.:,,.:'~ '::'i''<-, :r. 'T'7"F'!":, ................... !-!!::'!:;.'F't.,.I .r,. 3"I..I ;:~'~t:,;i;i; Ti.Il!:: i::'(:)l...L.O{.;! I i',!I".; I 'i"Ei"i,? F:'l...E.;.'~,:i.'li!. ;~'~C.t< N"'" ~ ~:: '~'. '" ' · -' ^ .,., ,'! i... ~ .... 5: I!i: i; F;: I F' '!" r-":'~ i'--.!)7:, !::; Iii: T U F;; i"--~ i.-.~ H E ;? ! (.'-.'. ;",! E D C (:)F' Y (? F' 'i" H I ,':; T l':.:/', i",! ,':'? i'1:1: f"f'?.,I ..... ~IL~ISKA OIL A#D G.4S g,O#$£RYATIOJV ~0,~M!$$10# Permit No. Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501;"3192 TEL E PH ONE (907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed ~--60 ?~- ~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, Chairman ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 TeJephone 907 276 1215 Harch 7, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 1H-Pad Wells 1-8 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG6/L20-tw Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany LEGEND ~ NOTES 542 I 4. P~OTRACTED SECTION CORNER. FUTURE WELL LOCATIONS. PERM.'~NENT SURVEY LOCATION MONUMENTS. EXISTING WELLHEAD FOUND THIS SURVEY. AS~ BUILT SPOT ELEVATION. PA[~ DIMEM$1ONS SHOWN ARE MEANS TAKEN FROM AS-BUILT SURVEY NOTES ELEVATIONS SHOWN ARE REPRESENTATIVE IrLEV- ATIONS TAKEN FROM AS-BUILT SUNYET NOTES. ELEVATIONS ARE BASEO ON $OtNO-~P VERTICAL DATUM. ALL COORDINATES SHOIN ARE ALASKA STATE PLANE COORDINATE SYSTEM, ZONE 4. SECTION CO~NERS SHOWN ARE BASED ON ALASKA PROTRACTION SYSTEM, THE ENTIRE AI~EA LIES WITHIN TI2N, RIOE, UMIAT MERIOIAN~ ALASKA. ALL AZIMUTH SHOWN ARE ALASKA STATE PLANE GRID AZIMUTH. ALL OISTANCE SHOWN ARE TRUE INSTANCES. · ~lJ~'%~l, I liI'"~IY C[#TIFY l#&l l,IS lS-~T M ~KL ~TE 'IN~ ~' A~-BUILT DRILL ~ITE "I-H" ~ ARCO Alaska, Inc. ARCTIC S~EYl~, I~. I !1 .......... ' I""': "'~' .......... q '~1~ I .......... I ..... '*" , '~ : .... I '- I" I- ' NSK-S.~.,-,q SW CO~ '0 --' I AZ IT$'4T'S$"-- ITSO.O' TRUE ~_ N: '~,979,~S~5 I / llll CONOUCTOR HOLE LOCATION~ WITHIN SECTION ~'1 FNL I F~L COU~DtNATES ~' · 5,910,0~,4 .eS 549,551 .90 S, ST 9,9'~,~. I S 549,560 .~,$ 549 ~ZO1.04 549,19Z. I0 549, lB $. 14 ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 31, 1983 Chat Chatterton State of Alasl<a Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99504 Commission Dear Chat' Attached are subsequent operations at Kuparuk. call me at 263-4528. notices on If you have Ryan L. St ramp Kuparuk Operations Coord i nator RLS/kjc Enclosure ×c' E. A. Simonsen - AFA 311 H. C. Vickers - AFA 326 L. M. Sellers - ANO 332 several of our any questions, recent please A~CO Alaska, ii;c. is a s~Jb~idi~:l'y of AttarHi-,:RichfieldCompany STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION CO~v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-115 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50~29-20792-00 4. Location of Well Surface Location' 791' FNL & 1148' FEL, Sec. 33, T12N, R10E Bottom Hole Location' 1454' FSL & 1278' . FWL~ Sec. 28, T12N, R10E 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 85' (RKB) I ADL 25639 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1H-3 11. Field and Pool Kuparuk River Field Kuparuk River Oi 1 Pool 12. 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 k~ ; Repairs Made [] Other Pull Tubing [] Other ' "FI':' 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). Plans to stimulate the Kuparuk sands in Kuparuk River Unit well 1H-3 ~ncelled due to the probability that a fracture treatment would result in an excessive increase in the well's GOR. Wells 1H-4 and 1H-8, southern offsets to the subject well, are currently shut-in due to excessive gas production (GOR's of greater than 5000 CF/BO). With the marked north-south trend of gas movement exhibited in this area of the field, we feel that fracturing wel 1 1H-3 would almost certainly accelerate gas breakthrough into this wel 1 . We have, therefore, cancelled our plans for this treatment. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~--~/~-~ L' ~ cT~:c~t~oC:so~fo:p,.... :rovC::~n~s:~n use Kuparuk Title Operations Coordinator Date 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 [ .~60 Anchorage, ~.-, ,l(a 99510 Telephone 907 277 5637 November 22, 1982 C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001-Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Please find attached the well completion reports for the following producing/injecting wells: 1B-9GI 1H-3 1B-10GI 1H-4 1B-11GI 1H-6 1E-11 1H-7 1E-14 1H-8 1E-15 Very truly yours, S. Dayton Area Operations Engineer slz Attachment cc: L. M. Sellers E..~A. Simonsen R. L. Stramp H. C. Vickers AN0-332 w/attachments AFA-311 w/attachments AST-308 w/attachments AFA-326 w/o attachments ARCO Alaska, Inc. is a Subsidiary of Atl~nticRichheldCompany STATE OF ALASKA -- ALASKA~_..- AND GAS CONSERVATION CC. MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE E~ 2. Name of Operator 7. Permit Number ARCO Alaska, :[nc. 82-115 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 BO- 029-20792 4. Location of well at surface /~1 ' I-NL, 'I'I/4U' I-LL, bec 3~, I1ZN, I~IUL, UM 9. Unit or Lease Name Kuparuk River Unif. At Top Producing lnterval 970' FSL, 1616' F~/L, Sec 28, T12N, R10E, UM lO. WellNumber 1H-3 At Total Depth 1/45/4' FSL, 1278' F~/L, Sec 28, T12N, R10E, UH 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 85' RKB ADL 25639 ALK 464 Kuparuk River Oil Pool 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 7/24/82 8/5/82 8/9/82I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafros't 8155' 7130' 80/45' 70/43' YESE~ NOEl 2030' feetMP 1600' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP, Cal/GR, DIL/SP/SFL/GR/FDC/CNL, CBL/VDL/CCL/GR, Gyro/eCL, GR/CCL 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 78' 24" 300 sx AS II 10 3/4" 45.5# K-55 Surf 2831' 13 1/2" 1100 sx AS III & 253 sx AS I 7" 26# K-55 Surf 8141' 8 1/2" 985 sx Class G Cml & 250 sx AS II ._ 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) 718/4-7220' w//4 SPF 90° Phasing 3 1/2" 7107' 7031' 7276-7305' 7/476-7/481 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7/490-7513' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A . -,, 27. PRODUCTION TEsT ,.. Date First Production . ; I Method of Operation (Flowing, gas lift, etc.) 8/15/82I Flowing , Date of Test Hours Tested PRODUCTION FOR OIL-BBL 'GAS-MCF WATER-BBL CHOKE SIZE GAS*OIL RATIO 8/18/82 22.7 TEST PERIOD I~ 540 165 -- 96/64 ,305 Flow Tubing Casing Pressure CALCULATED O L-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 190 __ 24-HOUR RATE I~ 579 176.5 -- 21 .2 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · Form 10-407 Submit in duplicate Rev. 7-l-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TES' NAME Include interval tested, pressure data, all fluids MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk N/A River Form. 7142' 6308' Base Kuparuk River Form. 7581' 6673' s~. LInT OF ATTACHMENTS N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ Title Date i recovered and gravity, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a ,separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item :27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ' Item 28: If no cores taken, indicate "none" ARCO Alaska, Inc. Post Office B~,~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Landon B. Kelly Kuparuk Operations Manager September 16, 1982 Mr. Chat Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Chat' Attached i s a stimulate Kuparuk treatment. If you 263-4528. R. L. Stramp Kuparuk Operations Sundry River have Notice indicating Unit well 1-H3 any questions Goord i nator RLS/b xc' L. M. Sellers- ANO 332 L. A. Blacker - AFA 330 E. A o Simonsen - AFA 311 H. C. Vickers - AFA 326 our with please intent to a fracture call me at ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2' N a~,°~ 8P e/~,~, S K A, INC 7. Permit No. · 82-115 · 8. APl Number 3'AdCresso. BOX 360, ANCHORAGE, ALASKA 99510 5o-029-20792-00 4. Lo~ation.of Well burtace Location' 791' FNL & 1148' FEL, Sec. 33, T12N, R10E Bottom Hole Location' 1454' FSL & 1278' FWL, Sec. 28, T12N, R10E 6. Lease Designation and Serial No. ADL 25639 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1H-3 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late ~ Abandon [] Stim u lat ion Repair Welt [] 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). ARCO Alaska, Inc. proposes to stimulate the Kuparuk sands in this well with a gelled diesel fracture treatment consisting of approximately 50,000 gallons of gelled diesel, 20,000 pounds of sand and 45,000 pounds of bauxite. All pumping equipment will be pressure tested to 5000 psi and treating pressures will be maintained below this valve. All circulated and flowed fluids will be diverted to tanks Temperature logs will be run both before and after the define the treated intervals. A pressure buildup test will the treatment to analyze the effects of the stimulation. work will be done through a 3000 psi lubricator. on location. treatment to be run after All wireline Expected start date is September 20, 1982. Sub.~eq~e;~t Work rteported Form No./~ J)at~a __/_/~15 '3 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe _ ~- ° Title Operat ions Coord i nat, or The space hew for Commission use Date Conditions of Approval, if any: Approved by ORIGINAL SIGNED BY LONNIE C. SMITIi Approved Copy Returned _ By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TO: William VanAlen FROM: D. W. Bose/L0rie L. Johnson Transmitted herewith are the following: P!.V~SE NOTE~ F - FILM, T - TAPE _ , PC - PHOTOCI)PY ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 KUPARUK ENGINFE. RING TO: William VanAlen D. W. Bose/Lorie L. Johnson Transmitted her~qith are the following: PI.FASE NOTE B~~L- BI/3EL~EP~, F - FII~I, T - TAPE, PC - PHOTOCOPY DATE: ARCO ~KA, INC. ATIN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHdR~GE', AK. 99510 KUPARUK ENG~ING TO: William VanAlen FROM: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PI.VASE NOTE: BL-.BILrELINE, S - SEPIA, F - FILM, T- TAPE, - PHOTOCOPY/; ~PLEASE RESURN ~IPT TO: DATE: ARCO ALASKA, INC. ATI~: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 AHC(J AlaSKa, Inc. Post Office Bo, Anchorage, Al ~ 99510 Telephone 907 ,,.. ,z 5637 August 24,.1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001'Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton· Enclosed are completion reports and gyroscopic surveys for the fol 1.owi ng wel 1 s' DS 2-25 DS 1H-3 If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. Van Dusen District Drilling Engineer PAV/JG:sm Enclosures GRU1/L80 ARCO Alaska, Inc is ~ subsidiary of Atl~nlicf~ichf,rldCc, rnparw TO: William VanAlen FRC~: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PI.WASE NOTE: BL-.BI335~INE, S- SEPIA, F - FILM, T- TAPE, DATE-' ATIN: LORIE L. JOHNSON - AF~/311 P. O.-BOX'360 ANCHORAGE, AK. 99510 . . A[lantic Ritchfield Company Arco Alaska, Ina. To: Wm.~ Van Al'en/Sate of 'AK · . . Date: 31 AUgust, 1983 TRANS}~TTAL From: EXTENS ION/EXPLORATI ON' . Transmitted herewith are the following: Mud logs 'from the folio.wing wells' lA-5 '~'. ' g-ll-81 1A-8-(~West'Sak 12) 7-22-78 1B-5~West Sak 7) '11-27-77 '~ " l-l-S1 1C-4j lC-5 ~ 2-9-81 lC-6~ 3-1.-81 1D-4~ 12-31-79 1O-8'~West Sak 8) 4-7-78 1F-5j' 8-20-82 10-4~ 10-12-82 1H-3~ 7-24-82 1H-6j 5-19-82 1Y-14j 2-4-83 2C-6 j 7-8-83 2C-7~~ .. ~J .. 6-29-83 2X-2 / 7-2-83 2Z-4-~, ....... 6-10-83 Also" included is an expanded' core log from well 2X-2, 7-2-83. A blueli'ne copy and a Sepia is provided for each well. . R~eipt Acknowledge}, R'~turn receipt, to: Arco Alaska, Inc. Attn: XM~X~N~PYaY~ E. McAlister P.O. Box 100360 Anchorage, AK Prepared by: B.Byrne 99510 .... : STATE OF ALASKA '- ALASKA L AND GAS CONSERVATION C! dlSSION WELL COMPLETION OR RECOMPLETIOh REPORT AND LOG 1. Status of Well Classification of Service Well OILYE] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-115 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20792 4. Location of well at surface 9. Unit or Lease Name 791' FNL, 1148' FEL, Sec. 33, T12N, R10E, UM ~LOCATIoN~''~-' Kuparuk River Unit VERIFIED At Top Producing Interval , 10. Well Number 987' FSL, 1602' FWL, Sec. 28, T12N, RIOE, UM Surf, [:-- 1H-3 / AtTotal Depth B.H. [~- -1 11. Fieldand Pool 1454' FSL, 1278' FWL, Sec. 28, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 85' RKB ADL 25639 ALK 464 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 07/24/82 08/05/82 08/09/82 N/A feet MS L 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 8155'MD,7130'TVD 8045'MD, 7043'TVD YES ~ NO [] 2030' feet MDI 1600' (approx) 22. Type Electric or Other Logs Run D IL/GR/SP, Cal/GR, D IL/SP/SFL/GR/FDC/CNL, CBL/VDL/CCL/GR, Gyro/CCL, GR/CCL. 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 78' ~_4u 300sx AS II 10-3/4" 45.5# K-55 Surf 2831' 13-1/2" ll00sx AS III & 250 sx AS I 7" 26.0# K-55 Surf 8141' 8-1/2" 985 sx Class G & 250-sx A: II 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) 7184' - 7220' 3-1/2" 7100' 7031' 7276' - 7305' 12spf 7476' - 7481 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7490' - 7513' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST .-. Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BB'L GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r)'" Press. 24-HOUR RATE "Ir 28. CORE DATA Brief description of tithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~ . , . Form 10-407 GRU1/WC26 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand Top -Top b~wcr ~nL~ ,. GEOLOGIC MARKERS MEAS. DEPTH 7183' 7307' 7466' 7581 ' TRUE VERT. DEPTH 6343' 6447' 6579' 6673' I / 30. FORMATION TESTS Include interval tested, pressure data, all fluids ~ec(~vei'~t an~t !uavily, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge , Sr. Drilling Engineer Title INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report a~d 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 Punnp, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". KUPARUK 1H-3 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 0200 hrs, 07/24/82. Drld 13-1/2" hole to 2846'. Ran DIL/GR to 2840'. Ran 66 jts 10-3/4", 45.5#/ft, K-55, ERW csg w/shoe @ 2831'. Cmtd 10-3/4" csg w/1100 sx AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form. to 12.5 EMW - ok. Disp well to xc polymer mud. Drld 8-1/2" hole to 3350'. Ran DIL/GR/SP & Cal/GR to 3350'. TIH w/O.H, test tools. Tst tool & DP to 1300 #. Set inflatable pkr @ 3306' w/MFE tool @ 3250' closed. RIH W/HP/CCL/Gradio/Fluid sample to 500', cycle MFE tool open for flow tst - no fluid loss on backside. RIH w/logging tools to 3150': Bled DP pressure to 1000 psi - no fluid entry Bled DP pressure to 750 psi - fluid level @ 3021' 229' rise Bled DP pressure to 600 psi - fluid level @ 2898' 352' rise Bled DP pressure to 500 psi - fluid level @ 2843' 407' rise Bled DP pressure to 450 psi - fluid level @ 2797' 453' rise Stuck logging tool string @ 3180'; worked free & POOH. Release inflatable pkr. POOH. Produced fluid was mud filtrate Chg BHA; TIH; wash & ream 90' to btm. Drld 8-1/2" hole to 7861'. Ran DIL/SP/SFL/GR/FDC/CNL f/7860'-2831'. Shot sidewall cores. Cont drlg 8-1/2" hole to 8155' TD (08/05/82). Ran 7", 26#/ft, K-55, BTC csg w/shoe @ 8141'. Cmtd 7" csg w/985 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld DV tool. Arctic packed 7" x 10-3/4" ann w/300 bbls H20, 250 sx AS II, & 139 bbls Arctic Pack. Tstd csg to 1500 psi - ok. Ran CBL/VDL/CCL/GR & gyro/CCL. Drld to 8045' PBTD. Disp mud w/brine. Ran 3-1/2" completion assy w/tail @ 7100' & pkr @ 7031'. Ran GR/CCL. Tstd tbg hanger to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp brine w/diesel (300 bbls). Set pkr w/3000 psi. Closed SSSV & bled tbg press to 500 psi & monitored for 30 min w/lO0 psi on ann. Press tbg to 1800 psi & opened SSSV - observed press increase to 2700 psi. Bled tbg & press. ann to 1500 psi - ok. Dropped perf bar & perf'd. Flowed well. Dropped ball and released Vannguns. 2300 hrs, 08/09/82. JG'llm 08/25/82 GRU/DH36 Closed SSSV. Secured well & released rig @ COHPLETION REPORT ARCO ALASKA,INC. GYROSCOPIC SURVEY ~RADIUS' OF CURVATURE METHOD OF COMPUTATION COI~PUTED FOR'SDI BY OCEANTECH(FM LINDSEY ~TRUE MEAS, DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D H DEG, RECORD OF SURVEY 23 AUG 82 KUPARUK H-3 KB ELEV '85, JOB NO 1392 TOTAL COORDINATES FT. C.LOSURES D I STANCE ANGLE D H ..DOG LEG SEVERITY DEG/1.OOFT '0 iO 0 100 0 14 200 0 11 30O 0 17 400 0;10 :500 1 44 6:00 5 S 7:0'0 8 19 · .8:00 12 4 · 9'0'0 16 28 1000 2:0 1 1100 21 26 12:00 20 53 t300 19 43 14:00 18 46 15:00 19 0 1600 18 11 1700 18 8 1800 18 14 1,9'00 18 55 2000 19 50 2100 21 25 -22'00 23 8 2300 25 36 2400 26 39 .:00 10'0.'00 200 .~O0 3,00. O0 .4.00. O0 499.98 599.79 699.09 797:5o 894,39 989,35 1'082,88 1'176,13 1269.92 1364.33 1458,95 1553.73 1648.75 1743,76 1838,55 1932.88 2 026.47 2119,01 221 O, 09 2299.87 · -85.00 15,00 ', 115,00 215,00 315, O0 414.98 514. ?9 614,09 712,50 809,39 904,35 997,88 1091 ;13 t 184,92 1279.33 1373.95 1468.73 1563,75 1658.76 '1753.55 1,847,88 1941 ,47 2 034,0'1 2125.09 2214.87 N ,~og H89,80W S 5.97W N83,22E HST,85E H86,40W H78.65W N63,42W N59.07W N59,42W NS6,22W N60,48W H61.17W N6 O, 02W NSS.67W NS6,65W N56,23W N54,77W NS4.43W N54.25W NS4.33W NS4.08W N53,28W N53.68W N53.37W ./ ,00 S ,,.00 W .00 $ 9:0 0 :0 g ,13 H ,13 W .18 H 44 54' 0 bt :.,09 S .38 W .39 S 76 18 18 W 5,56 14,07.:~H ~'3~TNitiOn~13$,38 N ~ 3~ 14. U 43,33 N 80,12 W 61,90 N 110,23 W ?9.49 H 141,75 W 96,53 N 171.97 W 113,33 N 200,32 ~ 130,65 N 227,66 W 148,27 N 254.23 W 165,92 N 279.91 W 184.00 N 305.35 W 202.57 H 331,23 W 221.93 N 358.17 W 242.53 t4 386.74 W 264.98 H 417.28 W 289.53 N 450.44 W 315.70 N 485.84 W 91.09 N 61 35 29 W 126,42 N 60 41 5 W 162.52 N 60 42 57,W 197,21 N 60 41 38 W 230.16 N 60 30 1 W 262,48 N 60 9 0 W 294.31 N 59 44 55 W 325.39 H 59 20 32 W 356.50 N 58 55 39 W 388.26 H 58 33 6 W 421.35 N 58 12 59 W 456.50 N 57 54 27 W 494,30 N 57 35 2 W 535.46 N 57 16 5 W 579.41 N 56 59 2 W ,OOO .233 ,050 ,100 ,117 1,572 3,351' 3.249 3. 755 4,400 3,570 1,527 ,557 1. 174 ,960 ,316 ,818 ,151 .105 .684 .917 ! .584 1 .721 2,468 1,052 SECTION DISTANCE ,.00 .18 ,24 '-.11 -.32 .67 5.78 16.76 34.21 58.,64 89,76 124.91 160.56 194,84 227.51 259.70 291.48 322.58 353.?5 385.57 41~.72 453,91 491.79 533.03 577.04 ARCO KUPARUK.H-3 .. GYROSCOPIC SURVEY JOB NO 1392 23 AUG 82 · ,TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M 2500 26 41 2.389,24 2600 26 14 2478,76 2710:0 26 ' G 2568.51 28!00 25 55 2658,39 2909 26 19 2748.18 3.0'00 26:39 2837,68 3100 26 32 2927,tl 3200 26 11 13016,71 3300 25 55 3106,55 34~00 26 39 3196,21 3500 28 3 3285,~03 3600 30 24 3372,30 3700 32 29 3457,61 3800 34 45 3540,88 3900 37 0 3621,90 4000 38 26' 3701.:01 4100 38 5 3779,53 -42.08 37 46 3858.41 4300 37 44 3937,48 4400 37 6 4016,90 45'00 37 9 4096,63 4600 36 43 4176,57 4700 36 37, 4256,78 4800 36 37 4337,.04 4900 35 46 4417,75 5000 34 26 4499,56 5100 32 18 4583,07 5200 33 2.7 4667.06 53~00 34 39 4749,91 SUB SEA 2304,24 2393,76 2483.51 2573,39 2663,18 2752,68 2842,11 2931,71 3021 , 55 3'111,21 3200,03 3287.30 3372,61 3455.88 3536,90 3616,01 3694,53 3773,41 3852,48 3931,90 4011.63 4091 .57 4171 ,78 4252. '04 4332,75 4414,56 4498,07 4582.06 4664,91 RECORD OF SURVEY DRIFT DIREC DEG, N53.47W N52.90W N52.5:OW N51,88W N51.37W NSO,40W N51,17W N50,33W H49..77U NSO.OOW N49,85W. N48,72bi N48.73W N48.-52W N4?.65W N48.OTW N46,95W N47.75W N47.38W N47,G3W N47o20W N47,18W N46,32W NG1,28W N66.orw N66,25bi TOTAl. COORDINATES C L 0 S U R E S D I STANCE . ANGLE D N ,'DOG LEG '. SEVERITY ~DEG/1;O.OFT 342,45 N 369,15 N 395,87 N 422,75 N 450,~08 N 478~:22 N 592,6:3 W .627,27 W 661 ,78 bi 696, :38 bi 624.21 .N 56 43 39 W 668,68 N 56 29 30. W~ 712.69 N 56 15 26 W 756,43 N 56 1 18' W 800.33 N 55 46 48 W 844,77 N 55 31 19 U 723.42 N 986,17 bi 762,15 N 1030.14 W 803,02 N 1075.'66 W 844,56 N 1121.58 td 886,:08 N 1166,90 Id 927,56 N 1211.93 bt 968.56 N 1256,77 W 1009,3J N 1301,28 W 1049.98 N 1345.52 W 1090,56 N 1389,33 bi 1131 .27 N 1432,92 bi 1171.90 N 1475.77 W 1209,05 N 1519,61 bi 1238,81 N 1565,81 W 1262.88 N 1614,44 W 1285.51 N 1665,66 W 1223,.06 N 53 44 15' 1281,43 N 53 30 14 1342.34 N 53 15 26 1404,00 N 53 1 lO' 1465,19 H 52 47 19 1526,15 N 52 34 15 1586,69 N 52 22 46 W 1646.83 N 52 1706,72 N 52 1766.23 N S1 1825.66 N 51 1884.48 N 51 1941.91N 51 1996.60 N 51 W W W. W W W W W W W W 12 4"W ~ I 58 W 52 10 W 42 33 W 32 49 W 29 35. W 39 0 W 2049,70 N 51 57 58. W 2104,03 N 52 20 24 W ,039 ,463 ,154 ,218 ,413 .386 ,192 ,386 · , 288 ,735 1 ,400 2,357 2,087 2,267 2,251 1 ,472 ,354 .525 ,301 ,647 .I04 ,460 ,I00 ,268 .862 2,555 3,157 I ,853 1.20! SECTION DISTANCE 621,90 666.44 710.54 754,39 798.41 842.99 887.75 932.14 976,03 1 02 O. 29 1 066,21 1114.99 1167,08 1222,36 1280.87 1341.91 1403.69 1464,98 1526,01 1586,61 1646.79 1706.70 1766,23 1825.66 1884.46 1941,89 1996.59 2049.69 2103,94 -ARCO KUPARUK , H-3 GYROSCOPIC SURVEY .JOB' NO 1392 23 RUG 82 HE~S, DRIFT DEPTH ANGLE D H 54~00 34 32 55:0"8 34 28 56i0:0 34 t3 5700 34 14 58:0!0 33 26 59~00 33 14 60'00:32 I~0 6100 3t 4 62~00 30 51 630'{} 32 5 6400 31 29 65-00 31 S 6600 30 45 6700 30 43 ~800 31 I 0 6900 30 45 7000 30 57 7t00 31 9 72~0 32 27 73.00 33 31 ~400 34 8 75.00 34 32 7600 35 11 , 7700 35 8 7800 37 15 79~00 38 10 RECORD OF SURVEY TRUE VERTICAL SUB DRIFT DEPTH SEA OlREC DEG, 4832.23 4747.23 N66.22W 4914.64 4829,64 N66.65W 4997.21 4912.21 'N66.80W 5079,90 4994,90 H66,7.SW 51'62.96 5077,96 N66.37W 5246.51 5161,51 N66.22bi 5330,66 S245.66 H65,07W 5415.82 53310.82 H63.93bi 55:01,57 5416,57 H62,~SW 5586.86 55.01.86 N61.32W 567'1.87 5586.87 H60.88W 5757,33 5672,33 HS~,83W 5843.12 5758.12 NSC. 15W 5929.08 5844.08 NST.97W 6014.84 5929.84 NSS.30W 610'0.60 6015.60 NS2.12W 6106.45 6101.45 N46.83W 6272.12 6187.12 N42.47W 6357.11 6272.11 H37.83~ 6440,99 6355,99 N38;57W 6524.06 6439.06 N37,70W 6606.64 6521.64 N38.02W 6688.7.0 6603.70 H36.98W 6769.95 6684.95. N33.83W 6850.13 6765.13 N33.OSW 6929,25 6844,25 N31,OSW TOTAL COORDINATES CLOSURES DISTANCE ANGLE D H . 1308,39 N 1331,03 N 1353,32 N 1375,50 H 1397,65 N 1419,75 N 1442;/03 N 1717.61 1269.53 W 1821.35 W 1873, ~04 1924.12 W 1974.43 bi 2:023,65 W 2159.18 N 2214.25 N 2269.1.0 N 2323.85 N 2378.17 N 2431.89 N 2484.87 N 1464 '6:oii:i;H;~;~ozo,~~= 2536,52 N 1537,45 N~o~JB~ir~ 26~1 ,SS H 1589;~1 N 2298.63 W 2794.51 N 1615.87 N 2342.23' W 2845.53 N 1644.15 N 2385.16 W 2896..93 N 1674.59 N 2426.62 W 2948.35 N 1707.90 N 2465,59 W 2999,34 N 1744,58 H 2501,83 bi 3050,03 N 1784,85 N 2535.79 W 31.00,96 N 1827.63 N 2569.46 W 3153.15 N 1071.42 N 2603,83 W 3206,58 N 1915.95 N 2638.44 W 3260.71 N 1961.29 N 2673.24 W 3315.55 N 2008,80 N 2707,01 W 3370,93 N 2058,64 N 2739.95 W 3427,15 N 2110,46 N 2772,44 W 3484,32 N 52 53 53 53 54 54 54 54 54 55 55 55 55 55 55 55 55 55 54 54 54 54 53 53 53 52 42 6 W 258W 23 1'I. W 021 W 3'1 36'W 43 54 W 54 t5 W 2 48'W 9 54'W 20 27 bi 23 55 W 25 14 W 23 26 W 17 23 W 6 39.'W 51 34 W 34 34. id 17 4.0 W 051 W 44 0 U 25 18. W 43 13 W THE FOLLOWING IS EXTRAPOLATED TO TD 8155 38 10 7!29,73 7044,73 N31oOSW 2245.42 N 2853.79 W 3631.26 N 51 48 .. :.DOG LEG SEVERITY DEG/IOOFT ,117 · 154 .254 ,023 ,808 .205 1 ,115 1 .141 .337 1 .317 .612 .488 .378 .311 .844 ,931 1 ,412 I , 185 1 .863 1. 090 .674 .413 ,735 I .450 1.150 1 . 193 .000 SECTION. DISTANCE 2158.92 2213.72 2268.23 2322.57 2376.41 2429.61 2482.07 2533.21 2583.59 2634.94 2686,92 2738,27 2789.19 2839,93 2891.16 2942.57 2993.79 3 044.95 3096.55 3149,46 3203.55 3258.28 3313.67 3369,58 3426.30 3483.87 3631.26 BOTTOM HOLE CLOSURE 3631,26 FEET AT N 51 48 13 W ARCO KUPARUK H-3 GYROSCOPIC SURVEY ,lOB HO '1392 NEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. '23 AUG 82 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTIOH TOTAl. COORDINATES :0 O, -85 '0 185 185, I'00 0 285 285, 200 385 385. 300 0 485 485, 400 0 585 585. 500 0 686 685. 600 0 78? 785, ?00 2 890 885. 800 5 995 .985. 900 10 11'02 '1085, t000 17 :12:09 1 185, 11 O0 24 1'316 1285, 1200 31 1422 1.385. 1300 36 1527 1485, 1400 42 1-633 1585, 1500 47 1738 1685. 1600 53 1844 1785, 1700 58 1949 1'885. 1800 64 2056 1:985 , 19 00 70 2163 2085. 2000 2272 2185. 21 O0 87 2383 2285, 2200 98 2495 2385. 2300 110 2607 2485. 2400 121 2718 2505, 2500 133 2830 2685. 2600 144 · 2941 2785. 2700 156 3053 2885, 2800 167 3165 2985. 2900 179 3276 3085, 3000 191 3387 3185, 3'100 202 3500 3285, 3200 214 3615 3305. 3300 229 3733 3485, 3400 247 2 3 6 5 6 8 9 11 12 11 12 11 12 11 12 12 11 12 15 18 ,90 $ ,04 S .33 S .24 S ,.,?0 $ '1.57 H 4,74 N 12.74 H 25,27 N 42.47 N 62,31 N AISle-- '81,12 N Scientifi~;~. 22 H ~ · .01 H Drilling 135.54N Internatl-~:~!Ol H '172,79 N 191,99 H 211.98 N 233. I 7 N 256,46 N 202.51 H 3'11.27 H 34t. 18 Fi 371. O0 N 400.79 H 430.78 H 461,55 N 493.26 N 524,65 N 556.04 N 587,74 N 620.91 H 657,54 H 698,57 H ,00 .37 . '19 .21 1,13 4.72 15.14 30.20 51,28 · 78.82. 11.0,96 144,69 1.76.62 206.31 235.09 262.74 289.61 316.50 344.32 373,79 405.79 440,91 479,87 520.17 560, O0 599,02 637.48 676,03 714.70 753,37 791,09 828.68 868, I 1 910.91 957,86 W W W E E W W W W W W,, W W W W: W W W' W' W W' W' W W W W W W. W W. W. W. flRCO KUPARUK H-~ ~YROS~OPI¢ SURVEY .dOB NO 1~92 MEASURED DEPTH AHD OTHER DATA FOR EVERY EVEN 100 FEET .OF SUB SEA DEPTH, :TRUE · MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 23 RUG 82 3854 3585, 3500 269 3980 3685. 36'00 294 4107 3785. 3?00 ' 321 42.34 3885., 3800 348 4360 3985, 3900 374 4 485 4!085, 4000 '4 O0 4611 4185. 4'100 425 4735 4285, 4200 450 4860 4385. 4300 474 4982 4485. 4400 497 51 02' 4585. 4500 517 5222 4685, 460'0 536 5;343 4785, 4700 557 5464 4885, .4800 579 5;585 4'985. 4900 600 57:06 5085. 5000 621 5826 5185. 51 0'0 641 5946 5285. 5200 66 0 6064 5385. 5300 678 6181 5485, 5400 695 '6298 5585. 5500 712 6415 5685, 5600 730 6532 ' 5785. 5700 747 6649 5885. 5800 763 6765 5985, 5900 780 6882 6085, 6000 796 6995 , 6185, 6100 813 7115 6285., 6200 830 2233 6385. 6300 848 2353 6485. 6400 867 7474 6585, 6500 888 ?595 6685. 6600 91 0 7719 6785. 6700 933 7844 6885. 6800 958 7971 6985, 6900 985 22 25 27 27 26 26 25 25 24 ~/,!i' 23 744 .~i09 794.52 847.43 900.1 O 952.17 '10103,39 ~054,25 104.84 '155.53 202', 96 19 1429,93 18 1456,43 17 '1483,1 0 17 1511 .44 18 1541 . 36 17 1571 ,51 16 1'602.09 17 .1634,04 16 1668,91 17 1707.31 17 175 O. 38 18 1798.93 19 185 O, 64 21 1904.25 22 1959,22 23 2017.97 25 2081.13 27 2147.99 N N N N N H N H. N N N N N N N N N N N N N N N N N H H N N N N N N N N 1'009,68 bi 1066,31 W 1124.76 W 1181.,98 W 1238,91 W 1294. ?? bi 1350,13 W '14.04.69. bi. 1 458,58 U 1511,65 bi 1566.;88 W. 1625,33' W' 1687,,82 bi 175.0,85 W 1813,70 Id. 1876,21 bi 1937,42 bi 1997,25 bi.' 2054,13 bi 2108,14 bi 2162,10 bi' 2216,23 Id 2268,72 U 2319,94 ~ 2370,31 U 2419,24 U 2464,95 ~ 2507,07 ~ 2546.78. U 2582,65 ~ 2629,32 ~ 2671,68 ~ 2713,14 ~ ,.. 2754,36 U 2795,06 ~ 'ARCO KUPARUK H-3 GYROSCOPIC SURVEY ,JOB NO 1392 HEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE MEASURED ,VERTICAL SUB DEPTH ~ ,DEPTH SEA MD-TVD DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 8098: 7:085. ?00'0 '1 013 28 2215.3'! N 2835.64 W Scientific Drilling International ,ARCO KUPARUK~H-3' GYROSCOPIC SURVEY JOB NO '1392 AUG 82 INTERPOLATED .VALUES FOR EVEN '100.0 FEET OF MEASURED DEPTH, TRUE MEASURED ,¥ERTICAL DEPTH DEPTH SUB SEA TOTAL COORDINATES !0 O, -85. ,~00 $ , '1,000 .989, 904, 43.33 N 8.0. 2:0'0-0 1933, 1848, 22! ,93 N 358, 3/)00 2838. 2753, 478,22 N 4:00.0 37:01. 3616. 803,02 N 1,075. 5000 4500. 4415. 1209.05 6-000 5331. 5246. 1442,03 N 2,023. 700:0 6186, 6101, 1707.90 N 2465, 8~.0'0 7!0.08, 6923, 2163,39 H '2804, ~ · '00' Al 17W 39 W 66 W 61 W 65 W. 59 W 34 W Scientific Drilling International ARCO KUPARUK H-3 .' . GYROSCOPIC SURVEY JOB NO 1392 INTERPOLATED TRUE ~ERTICRL DEPTHS, COORDINATES AND'CLOSURES FOR GIVEN DEPTHS TRUE MEASURED ~ERTICAL TOTAL COORDINATES C L 0 S U R E DEPTH DEPTH DISTANCE ANGLE D M S 23 AUG 82 . SUB 'SEA TOP/UP SD 7583 BASE/UP SD 73.07 T.OP/LOW SD 74'66 BASE/LW SD 7581 PBTD 8445 TD 8155 6342,75 17.77,71H 2530.16 6446.83 1830,66 N 2571,87 6578,61 1900,78 H 2626,61 6673,16 1952,57 H 2666,65 ?i043,25 2187,20 N 2818.?0 7129.73 2245,42 N 2853,79 3092.24 N 54 54~25 ~' 6257..75 3156.87 N 54 33 24 W,.-' 6361.83 3242,23 N 54 6 29 W 6493,61 3~05,0g N 53'47 15 W 6588.16 3567,76 H 52 11 23 W 6958,25 3631,26 H 51 48 13 ~ 7044,73 c ent flc Drillincj Internat' .~ . : ................. ' ARCO ALASKA .INC. .... ' ........... KUPARUK H-3 . ............ ~ ............ ~ ................. ; ......... ; ............. GYROSCOPIC SURVEY ! ........ :· ' -'--. ....... ~" -.": .... · ..... 7 . :. ' ...... ~ .... ~-*}-. ............ ~ - '~ ;,· -}.' ...... · ....... · .' * -; '. · · ..... + ~ ............ . _ .......... .......... ... { ._ ~.... . ...... .......... , / ' * * : ~ ~ . .... ' )0~ - 1600 ..... ' ...... ~ ................. ' _ ....... ~__.,.. ~ ....... -~ .................. H0. R 1Z'0 NT A L._ V I E W ....... ..... ARCO ALASKA' INC .... · ............ KUPARUK H - 5 .................. "- ............. ; ......... kA'5.1'u$ OF cURVATuRE: .............. i ................., ,GYROSCOPIC ;SURVEY .... .:. ..... $.C. ALE_J... 1 ....= .. t OOO..~'_].. ....... [ ....... . · . . ............... AUOUST ~_5, 1982 ] _ . .. . .................... . ~ ...... - ..... . .......... , i ' ' i ': .... ' _ _ .', ............. ~. ........... ; . _.: ' :- " : :-'-~'.'~i .... · ........ -_. ~ ........ : ' . , ~ . . . . .........T V.D -- ~..- 7~ 1-3_0.-. ~ ................................. ' L - , ' 'T M D -= .Si 55 ': _ /' . ...' . ~ ':. '. ...... , ................ . ..,.o~X~'''~~' ' ,,... : . : . . ~ .... : .......... "-' ~o~ ~~. - · .... ~-- - ; - - ~/ ........ ', ' - . .... ~ ...... ~. . : R ........... ~ -, . ~ ................ ~ ...... ......... ~_ . ~ ; ....... : .. , .... ~ ..... . . . . ................................ ...... [ ............ .. Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, yell Name and Reports and Materials to be received by: Required Date Received Remarks Ccr~letion Report Yes ,, Wel 1 History Yes _S~les ~ / Core ~scription . ..... InClination Su~ey ~ , Drill St~ Test Re~s ~ /~ ~S R~ Yes _ KUPARUK ENGINEERING TO: DATE: WELL NAME: Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM,~ RECEIPT ACKNOWLEDGED: ,. ,~ . -*'~ ~,,~,,,j~, DATE: ARCO ALASKA, INC ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHO~GE, AK 99510 ~CO Alaska, Inc. Post Of.fice E .) Anchorage, Alas,',a 99510 Telephone 907 277 5637 August 9, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for July on these drill sites' 2-25 13-25 18-3 2-26 13-30 1E-15 6-17. 13-33 1H-3 6-18 14-21 1H-4 6-19 18-2 Also enclosed are three subsequent sundry reports for Kuparuk 1H-5 and completion reports for' 13-21 15-'6N 13-24 18-1 13-26 1E-14 14-17 1H-5 14-22 The gyroscopic survey for DS 2-22 needs to be reran; a com- pletion report for thi-s well will be submitted when the approved survey is received. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG'sm Enclosures GRU1/L61 ARCO Alaska, Inc. is a subsicfiary of AtlanticRichf~eldC()mp;)ny STATE OF ALASKA -~ ALASKA ~AND GAS CONSERVATION CC MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS il. Drilling well ~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 360, 4. Location of Well at surface Anchorage, AK 99510 791' FNL, 1148' FEL, Sec. 33, T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 85' RKB 6. Lease Designation and Serial No. ADL 25639 ALK 464 7. Permit No. 82 -115 8. APl Number 50- 029-20792 9. Unit or Lease Name Kuparuk River Unit 10. Well No. iH-3 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of .... July ,19 82 d2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0200 hrs, 07/24/82. Drld 13-1/2" hole to 2846'. Ran logs. Ran, cmtd & tstd 10-3/4" csg. Drld 8-1/2" hole to 3350'; ran logs & tsts. Continued drlg 8-1/2" hole to 4730' as of 07/31/82. See Drilling History 13. Casing or liner run and quantities of cement, results of pressure tests 16" 62 5#/ft H-40 conductor set @ 78' Cmtd w/300 sx AS II 10-3/4", 45.5#/ft, K-55, ERW csg W/shoe @ 2831'. Cmtd w/ll00 sx AS III & 250 sx AS I. See Drilling History 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR to 2840' DIL/GR/SP to '3350' Cal/GR to 3350' ,.1 6. DST data, perforating data, shows of H2S, miscellaneous data Oil & Gas Cons. Co,'~rnis::ion 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil and Ga~'Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate KUPARUK iH-3 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 0200 hrs, 07/24/82. Drld 13-1/2" hole to 2846'. Ran DIL/GR to 2840'. Ran 66 jts 10-3/4", 45.5#/ft, K-55, ERW csg w/shoe @ 2831'. Cmtd 10-3/4" csg w/ll00 sx AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form. to 12.5 EMW - ok. Disp well to xc polymer mud. Drld 8'1/2" hole to 3350'. Ran DIL/GR/SP & Cal/GR to 3350'. TIH w/O.H, test tools. Tst tool & DP to 1300 #. Set inflatable pkr @ 3306' w/MFE tool @ 3250' closed. RIH W/HP/CCL/Gradio/Fluid sample to 500', cycle MFE tool open for flow tst - no fluid loss on backside. RIH w/logging tools to 3150': Bled DP pressure to 1000 psi - no fluid entry Bled DP pressure to 750 psi - fluid level @ 3021' 229' rise Bled DP pressure to 600 psi - fluid level @ 2898' 352' rise Bled DP pressure to 500 psi - fluid level @ 2843' 407' rise Bled DP pressure to 450 psi - fluid level @ 2797' 453' rise Stuck logging tool string @ .3180'; worked free & POOH. Release inflatable pkr. Chg BHA; TIH; wash & ream 90' to btm. Drld 8-1/2" hole to 4730' as of 07/31/82. MEMORANDUM State of Alaska ALASKA O~IL AND GAS CONSERVATION COMMISSION tterton DATE: August 2, 1982 THRU Lonnie C. Smith Commissioner FROM: Bobby Foster''~' Petroleum Inspector FILE NO: 108A/V TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO's 11{-3 Sec. 33, T12N, ~I£,E, Pe r~.~ t #82-115 TpesdaY,. Ju_ly_ 2_7,~. !982 - The BOPE test began at 6:30 and ~s completed at 7:30 p.m. As the attached D,©PE re[~rt shows there were no failures. In sum~ry, I witnessed the BOPE test on AP. CO's 1}~-3. 02-O01/~ Rev. 10/791 4/80 STATE OF AI,ASKA ALASF~A OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Wel 1 Operator Well.. ~.~ ~, ,-. . · Location: Sec ,'7' ': T ?//R/ .... ,~:, ri L~/~?"'" ~I ) Drilling Contractor Representative Permit # . L?:'::.Casing Set Location, General, Well Sign ,'~..-~ General Hous ek~ eiSing' Reserve pit -- . .... .~, Rig BOPE Stack Test Pres.sure ACCUMULATOR SYSTEM ~:'~-' "-~ "-" ps ig Full Charge Pressure~-~ .... ..... Pressure After Closure ,, psig 200 psig Above Precharge Attained: . rain-T2) sec Full Charge Pressure Attained: C~ rain C~ sec , / --~ ~ / / -) N 2 ~ ~' ~'lt ..... ~ [) s ig Controls: Master ' ' '% Remote': Blinds switch cover : .... " Kelly and Floor Safety Valves Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve , , Upper Kelly Lower Kelly Ball Type Ins ide BOP Choke Manifold No. Valves. No. flanges x_ ~ Adjustable Chokes Test Results: Failures Test Pressure Test Pres sure Test Pressure Test Pressure Test Pressure Hydrauically operated choke .......... --- :-~::.:m:-:--.:_~' ~'::~-~-~:-- .-:: ............. Test Time / hfs Repair or Replacement of failed equipment to be made within Inspector/COmmission office' notified. 'Remarks: days and Distribution orig - AO&GCC ........... cc - Operator i cc - Supervisor Inspector( July 19, 1982 Mr. Jeffrey B. Kewin Seniorr:r~ ilIing Engineer AF~ Alaska, Inc. Anchorage, Alaska 99-510 Ku~aruk River Unit 1}{-3 ARC'O Alaska, Inc. Pe~it No. Sur. Loc. ?91'FNL, I14-8'F~L, Sec. ~t~hole Loc. 1591'FSL, 960'F~qL, Sec. Dear ~r. Kewin: Encl~sed is the approved application for peri'nit to (~rill the a}~ove referenced wel 1. }Yell safe, plea and a inud log are not required. ^ continuous direetio-nal ~urvey is required aa per 2-0 AAC 25.050(b)(5). If avaita~Ie, a tape containing the digitized log infornmtion shall be submitted on all IOa-$ for copyinf;' except ex~erin'~ental log~, velocity surveys and cli?:,neter surveys. ~iany rivers in Alaska and their draina~'e systemics have been classified a~ imi~rtant for the spa~ning or mi~ration of anadroa~ous fish. £~peratton~-in these areas are subject to AS ~6.05.27~ and the regulation~ promul~g'ate~l thereunder (Title 5, ~.laska Administrative Code). Prior to eon~¥,encir~?.~ ~p~rati(~ns you n'~ay be contacted by the Habitat Coordinator's Office, Depari~ent ~f Fish and Canoe. Pollution of any waters of the .State is prohi[~ited by Al-', 46, Chapter 3, Article 7 and the regulation~ !~ro~'~ulgated thereunder (?tile l~, Alaska Adn~inistrative Code,. Chapter 70) I;'ederai }~ater Pollution C~nirot Act, as at, endS~. Prior c~n~encing o~erations you ~nay be contacted by ~ re[~resent~.tlve f~f the i~e~art~nent of 2nviron~;~entat C~nservation. To aid u~ in schedht'i~y field work, ~e ~ould a~{~reciat~,, your notifying; this ~ffiee ~ith. in 48'hour~ after the ¥~:11 i~ s~udded. We ~ould also like to bc n~tified ~o that ~ ret~resentative of the Con~n~is~ion ~my be 1:resent to ~,itne~ ~r. Jeffrey B. Kewin ~{uparuk River Unit 1H-13 -2- July 19, 1982 testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abando~i~ent, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatterton BY ORDER OF THF. CO~'~,~;$~,ON Chai rman o f Alaska Oil and Gas Conservation Commission Enclosure cc: Department of-Fish & Game, Habitat Section w/o encl. Department of Environ~mntal Conservation wlo encl. CVC: be ARCO Alaska, Inc. July 15, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1H-3 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1H-3, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity map indicating the relative location of Kuparuk wells 1H-3, 1H-4 and 1H-8. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. Since we expect to spud this well on July 20, 1982, your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. Sincerely, ~~n~..g Englneer JBK/JG:llm Enclosures GRU1/L50 inc. i:;; ~ub~:.idi~ry of AtianticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COL,,?IISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 791' FNL, 1148' FEL, Sec. 33, T12N, RIOE, UN 9. Unit or lease name Kuparuk River Unit At top of proposed producing interval Alaska Oil & Gas Cons. Target: 1320' FSL, 1320' FWL, Sec 28, T12N RIOE, UN Anchorage At total depth 1591' FSL, 960' FWL, Sec. 28, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 54.5' PAD, 85' RKB ALK 464 ADL 25639 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 ,10. Well number s~of~a_3 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 Miles NW Deadhorse miles 960' FI//L (~ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8338'HD, 7152'TVD feet 2560 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. MAXIMUM HOLEANGLE~7 o 15. Distance to nearest drilling or completed U-4 well@ surf 120' feet 18. Approximate spud date 07/20/82 2807 20. Anticipated pressures psig@_80°F Surface (see 20 AAC 25.035 (c) (2) _~L~0 psig@ 6_~R5 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight 16" 65# I?1/2" 10-3/4" 45.5# -- 8-1/2" 7" 26# 22. Describe proposed program'. CASING AND LINER Grade ~-g Length H-40 IPEB I K-ss [ TC J K-55 J BTC ] 8310, MD TOP TVD 80' 30' I 30' 2920' 30' I 30' I 28' I 28' I MD BOTTOM TVD · 110' 110' (include stage data) ±200 cf 2~950' 12700' I 8338' 7152' J I I 1000ax AS III 250ax AS II 1000ax "G" cmt. ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 8338' MD, (7152'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Maximum expected surface pressure is 2807 psig. Pressure calculations are based on virgin reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress 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 installed and tested upon completion of the job. The Ugnu interval will be open-hole tested. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED L/~..~v~f~.~ ~./~~ TITLE Senior Drilling Engineer The space bel¢ [o~o~mi~or~ ~se ~--- - CONDITIONS OF APPROVAL Samples required []YES [~LNO Permit number DATE APPROVED BY Form 10~01 GRU1/PD7 Mud Icg required Directional Survey required APl number []YES E~O [~YES []NO 50- 0 Approval date ,COMMISSIONER DATE July 19, 1989. by order of the Commission Submit in triplicate ' · I ' . ' ' ' ~ : ' ! ~ ~ ~ ':.-~.' · --L-4-- ' 4.- ~t~_..I_M _L_~. ,_-_ti._ i._~_.~. _ ,_-_ ._ .......... ~_._.-L_4- .... ~ ..... ~._+._.~.-_..--~.-.4.'-4-.-,.-- .- ~ I i : ! ; ..... ~ ............ ;--~-.;--t-~ .... -I-~ ...... 4-?+---+-!-~--~ ...... ?'--~--T--?'---t-T'T-- ..... '~-~--!---1--r-'t-~, .......... '="-T-. -.---.--~ ...... , -T-'!"--; ...... Y-T ......... '~ 'T-~ ~' ,'T, "-.,-i-': i ' . ' ! .......:~,,,t't"~,' ........................ 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X- ~ ...... ; ................... t---r-~che- u~, '~r--~---Zi~ i ; ; ' ' : ' -- .... 4-- _J-.Z .'.--'-:::.-i;~-i'i'Xilt'-i7-::::.'~ i- ~- - ............... i--: ....... ~ ............ 4 .............. ~--:--~-----4. .... ~ ......~-,--~ ..... ~ ..... : ..... ~ t ........... ~ ................ , .............. 4. .............. i ....... ; .... ~ ..................... :_; ...................... ~_:.~ ...... ; ......... ~=...z ....... ~:-~- ~ ............ ~ ........... t ............. ~ ........................... h--: .... 5000 PSI 'RSRRA BOP STA'CK -' 1%5/8" 16" Bradenhead 16" 2000 PSI x i0' 3~'~.3 ?SI czsing head t0" 3000 PSI tubing he~_d lO" 3000 PSI x 13-5/8" 5.000 FSI adapter spool 13-5/8" 5000 PSI pipe rats 13-5/8" 5000 PSI drilling spo31 w/choke and kill lin~ - - - 13-5/8" 5000 PSI pi~ ra~- 13-5/8" 5000 PSL bliad r~ -- 13-5/8" 5000 PSI an~lar - ' - _ . . . - - ~ . ~CCD4U~T0~ ~I~ ~T - . _ . . ~E~ ~'~ FILL ACtUaTOR ~E~I~ ~ P~P~ ~%'~ WIT~ HYDP~ULIC ~ID. WI~ 1500 PSI ~~ ~S~VE TIHE Tk~ C~E ~ L~ITS S~T~- ~ OFF. LDIIT IS 45 SE~:;~ ~I~ %LqE ~ 1~ PSI F~NIt~ PP~SU~. - 13-5/8' E, OP STAT.( TEST FILL BOP STACK .N¢D MY-.ffLmOLD 141 ~-!-I. J3'~-'TIC DIESEL. ~.ECI( TH. AT ALL HOLD C"'?,,,C~ S~------_~5 X.-~_ FULLY P,E- TRACTED. PREDETEF. HIt~E DEPT'-' T~,AT ~ ~-l_b~ k'ILL SEAT AID SEAT IX ~-'~U-Z~D. ?'~'~ I~ DOaN SCP,~,/S IN HEAD. CI. OSE ~¢~ULA~ PREYE;{rTER AND C-?3KES A~ 5'YPASS YALVES 0:( t. IA,'I, IFOLD. TF..ST ALL C[%4PO~E~ITS TO 250 FSZ A~'O 1-'~D FC~2 lO HIh'UTES. I~;C,.-REASE PRESSUP£ TO-I.,._~. PSI A~(D PJ~Li) FOP, lO MI')iUTES. BLEED TO Z.c%-R,O FSI. OP~(" 'ANHULAR PP,~/~,--~, AJ;D CLUE ~ SET PIPE ~_.q. I~;CREASE 'PRESSURE TO ~X)O FEI' ~'ID H~__D .q)R 10 CLOSE VALVES DIRECTLY UF'S17:._A'~ OF ~. ' BLEED D~,,'~tSTRE~{ P?.ESSb~'~~"- ~ ZERO ~ TO TEST ¥.-'LVES. TES l RE-L~,I.,,u UN'F_Si--'ED_ Y;-LYES, IF ~Y, ',~t'TH 3,303 PSi UP~.-'i?..r.~.;~ V;LVE A.'~D ZERO PSi D~':~~. BL="=/_D ~ ~--r__M TO ZLR0 PSI. - . ' OPgl TOP S~ OF PIPE P,A~ A.~D g.-O~-E SET OF PIPE Ih~.P. EAS. PRE~SU:-- TO ~-~J~ PSI ,-.,9 ..OLD FO., lO It!]~JTE. S. BLEED TO ZEF:D O?':J; BO]q'OH SE7 OF PIP~'"" .RAMS. 5AL'~ OFF ;;I:;g JOI,~ A~;D PULL ~3T OF ~____~5. CLOSE £LIND R;-.'.-'6 ;JiD" TEST t0 3000 PS! F.~L~ i0 BLEED TO ZERO PSI. ' SLI~..E )-~'IIFOLD' ;u','D LI,W~S ARE'"'"' F'u%.L ~ ~C - DIESEL A,'¢D ALL YALYE5 A.--"~ SET '~)~ F"OSI~I. TEST STA,qDPIPE YALYES TO 30~ .sSI. - TEST K.E'LLY COCz. S A,qD I,'~ZDE.SC~ TO 3000 fxj! R.ECO.~ TEST [)(FO.~'~TI(~t ~ :~...~..,,F"J~ ~ TEST FOP..q 5IG;I A:~D'"' S~ TO ~TLLI~ YISO~. - . . · PEF',FOP'.A CC)IPLE-FE BOPE ~ G'~.~ A I.~"EFZ I. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preven-fer. 5. 20" 2000 psi annular preventer. 6. 20" bell .nipple. 16" Conductor Maintenance & Operation 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines eYery 12 hours. 3~ Close annul ar preventer in the event that gas or fluid flow to surface is 'detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under any circumst~ances. --" Surface Dive ..... :,r Ssstem CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc ............. ....... ?- f3 -'{-~. (2 thru 8) i . . 3. 4. 5. 6. 7. 8. (9: thru 11) 10. 11. (4> Casg ,~ ,,,~-/~,~ ~12 thru 20) 12. 13. 14. 15. 16. 17. 18. 19. 20. (5) BOPEz,~ ? '?---~- 21. ~1 thru ~4) 22. 23. 24. Company Lease & Well No. YES NO the permit fee tached Is at ............................................ / Is well to be located in a defined pool ....... ........ Is well located proper distance ,from property line ...[iii ii'''is the affected: ' ........ .... ....... Is well located proper distance from other wells ........... Is sufficient .undedicated acreage available in this pool Is well to be deviated and is well bore plat included ' · Can permit be approved before ten-day wait ................... d f Does operator have a bon in orce .................................. Is a conservation order needed ...................................... ': Is administrative approval needed ................................... Is conductor string provided ...................................., ...~. Is enough cement used to circulate on conductor and surface~.r~g' Will cement tie in surface and intermediate or produCtion s Will cement cover all known productive horizons .......... ,. Will surface casing protect fresh water zones ...................... Will all casing give adequate off,from safety in collapse, tension ....... a.n.d, burst,.., Is this well to be kicked an existing wellbore Is old wellbore abandonment procedure included on 10-403 ............ ~---- /~/.~q' Is adequate well bore separation proposed .- ........................ ~.~," Is a diverter system required ....................................... ~~,~____ Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~P~PcPO psig . Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. REMARKS Additional Remarks: Geology: Engi~eer ing: :WK ~ LCS ~ BEW~~ rev: 01/13/82 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. bis TAPE VERIFICATION LISTING bUD O~,O,HOl YE~IFICATION LISTING PAGE ** REEL HEADER ** SERVICE NAME :SERVIC DATE ~8~/08/13 ORIGIN : REEL NAME :REEL ID CONTINUATION ~ :Ol PREVIOUS REEL { COMmEnTS :REEL CO~MEMTS ** TAPE HEADER SERVICE NA~E :SERVIC DATE {82/08/13 ORIGIN :1070 TAPE NAME .6~4~3 CONTINUATION # REV!OU$ TAPE. DEMENTS :TAP~I COMMENTS EOF ** FILE MEADER *, FILE NA~E :SERVIC,OO~ SERVICE ~AME ~ VERSION # : DATE ~ MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE t ** INFORMATION RECORDS ** CONTENTS CN SECT{ COUN: STAT{ CTRY: ~MEM PRES: ATLANTIC RICHFIELD COMPANY IH-3 10E 33 NORTH SLOPE ALASKA U,S,A, CONTENTS OILOOIE ** RECORD TYPE 047 ** UNIT TYPE CATE SIZE CODE 000 000 02~ 065 000 000 004 065 000 000 O08 065 000 000 003 065 000 000 00] 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 006 065 U~IT TYPE CATE SIZE CODE 000 000 007 065 bVP OIO,HO1 VERIFICATION LISTING PAGE 2 ** RECOPD TYPE 047 ** ** RECORD TYPE 047 ** COMMENTS ** AhASKA COMPUTING CENTER COMPANY : ATLANTIC RICHFIELD COMPANY FIELD = KUPARUK COUNTY : NORTH SLOPE BOROUGH STATE : ALASKA JOB NUMBER AT ACC: 10707,65413 RUN #3, DATE bOGGED: 4 A0G 1982 LDPI BOTTOM DEPTH = 7854,0 TOP DEP~..~H = 2700,0 BIT SIZE c I~ ~N LVP 0!0,H01VERIF'IC4TION LISTING PAGE TYPE FLUID = PODY~ER DENSITY = 10,4 LB/G VISCOSITY = 40 0 S PH = 9,~ FLUID LOSS = 6,0 C3 RMF : ~.950 ~ 64.0 DF ,!60 ~ 64.0 D~ R~C ~ 2,040 8 64.0 DP RM AT BHT - 1,809 ~ 148.0 DF MATRIX SANDSTONE THIS LISTING REPRESENTS A MERGED PRODUCT : RUNS ~1, #2, AND #3, jOB NUMBER AT ACC: 10707,65402 RUN #2, DATE LOGGED: 28 JULY 1982 BOTTO'~ DEPTH = 3352,0 TOP D~PTH = 2630. o, CASING : 16 I~) 106 FT. hVP 010,H01 VERIFICATION blSTING PAGE 4 MIT SIZE TYPE FbUI D OENSITY VISCOSITY FLUID LOSS RNF RMC :95 i~,4 ca 3,650 ~ 70,0 DF 4,380 ~ 68,0 DF 5,800 ~ 72,0 DF ],557 ~ 72'0 DF JOB NUMBER AT ACC: 10707,65367 RUN #1, DATE LOGGED= 26 JULY 82 bDP ~HGI4 BOTTOM DEPTH = 2840 FT, TOP DEPTH = 106 FT, CASING : 16 8IT SIZE = 13,5 IN ~ TYPE FLUID = WATER B~$E DENSITY : 10 LB/G LVP OlO.H01 VERIFICATIOM LISTING PAGE 5 VISCOSITY FLUID LOSS RMF RM AT BHT MATRIX SANDSTONE : 43 S = 10,5 C3 : 6,530 ~ 59 DF = 6,220 ~ 59 DF = 4,450 ~ 50 DF = 4.104 ~ 98 DF ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 1 66 8 4 73 6O 9 4 65 ,lin 0 I 66 0 DATUM SPECIFICATION BLOCKS ~NEM SERVICE SERVICE UNIT API API AP1 API FILE SIZE PROCESS SAMPLE REPR ID ORDER # LOG TYPE CLASS MOD NO, LEVEL CODE OEPT FT o 0 SFLU DIL OH~ 7 0 ILM OIL OM~E 7 0 ILD DIL OH~ 7 12 SP DIL ~V 7 1 GR DIL GAPI 7 31 NPH! FDN PU 42 68 CAb/ EON IN 42 28 OP.O EON G/C3 42 44 NCNL FDN =~ 34 FCNL FDN 42 34 G~ BGT GAPI 0 31 CI BGT IN 0 C2 BGT IN 0 0 0 0 0 4 0 0 0 4 0 0 0 4 46 0 0 4 0 0 0 4 32 0 0 4 2 0 0 4 1 0 0 4 32 0 0 4 3 0 0 4 0 0 0 4 I 0 0 4 92 0 0 4 0° o 0 68 68 68 68 68 68 68 68 68 ** DATA ** LVP 010,H01 VERiFICATI[i~',~ LISTING PAGE SP GR NCNL SP NCN[, SP GR NCNL C2 DEP? NCNL DEP~ SP NCNb DEPT SP NCNb C2 DEPT SP NCNb C2 DEPT NCN L C2 7889.OOOO SFLU -19 3435 GR 18.9844 CALl 411.O000 FCNL -999.2500 2,9258 ILM !8 9844 NPHI 8.'5000 DRHO 1~5.~875 GR 7800.0000 S~LI, -20.4219 GR 98 8750 CALl 2~o~:ooOo ~cN~ '999,2500 2.9668 !b~ 98.8750 NPHI 9.0469 DRHO 674.5000 GR 7700.0000 SFLU -22 5313 GR 91.8125 C&LI 2592,0U00 FCNb -999,2500 3.2598 IbM 91,8125 NPHI 9,2344 DRHO 726,0000 GR 7600,o000 8FLU ~42.8125 GR 03,8125 CAI, I 2216.0000 FCNI. -999.2500 3 8770 IL~ ~03~8125 ~PHI 604.5000 GR 7500 -60 43 tO00 -999 0000 SFLU 5313 GR 7500 CALI 0000 FCNL 2500 48 6250 IL~ 43,7500 NPHI ~08~,0000 GR 7~00.0000 SFLU 3.3,8125 GR 75.5625 CALl 2686.0000 FCNL -gg9.2500 5,2344 IbM 7~ 5625 NPHI 79~!67970000 GRD~MO 7300.0000 SFLU -63.4375 GR 44.3750 CAbI 31.26,0000 FCNL -999.2500 29.5000 II, M 44.3750 NPHI 8.9687 DRHO 1039,0000 UR 7~00, 57' 999~ 0000 SFLU ooo,o, !562 CALl 0000 FCNL 2500 6,4883 !LM 978.5000 GR 7100 114 1830 99q 0000 SFLU 1,3945 Ib~ 0938 GR !14 4375 NPHI 437~ CAt,,I 9' 0000 FCNL 455'851'6 DRHO .5000 GR 2500 2.7]8] ILD 42,4805 RHOB -0,4717 NRAT -999,2500 C1 2.9102 ILO 34,2285 RHOB 0,0449 NRAT '999.2500 C1 2.904] ILD 34.i797 RHOB 0,1040 NRAT -999,2500 Cl 3.0371 ltd 36,2793 RHOB 0.0781 NRAT '999,2500 C1 ]2,8750 ILD 29,7363 RHOB 0.0532 NRAT '999,2500 CI 4,5352 ILD 31,1523 RHOB 0,0020 NRAT '999.2500 CI 27.6563 6,921,9 ~70,24.61 RHOB 0342 NRAT -999,2500 C1 2.6004 2.0059 3.2891 -999.2500 2.8477 2,4277 3,0313 -999,2500 2.7695 2.4395 3.0430 -999.2500 2.8965 4375 -999,2500 25.9219 2.2988 2,7324 -999,2500 4.5078 2'4160 2.91,21 -999.2500 25,6094 '999 7,0039 ,3438 .6641 -999,2500 3047 -999' 72'4. ,2500 bVP 010,HO1 VERIFICATION LISTING PAGE 7 DEPT 7000 0000 SFLU SP '34,2813 GR G~ !20,7500 CAb! NCNb 1865,0000 FCNb C2 -999,2500 2,1562 !20,7500 9,9219 466,2500 NPHI DRHO GR DEPT 6900 SP -40 GP 141 NCNb 1927 C~ -999 0000 SFLU 0313 GR 8750 CALI 0000 FCNL 2500 3,0117 141'8750 9,9609 530,0000 IbM fIPHI DRHO GR OEPT S? GR C2 6~o0,0000 34,3125 201,2500 2206,0000 -999,2500 CALI FCNL 2,79]0 201,2500 9,6406 428,5000 IL. NPH! DRHO OEPT sP GR C~ 6?OO.OOOO -41,0625 1.30.6250 ~062,0000 999,2500 SFLU GR CALl FCNb 3.0078 _ ,289! 523,5OOO NPHI DRHO GR DEPT SP GR NCNb C~ 6600.0000 -31 5156 116.3750 2198,0000 'ggg,2500 SFLU GR CAb! FCNL 2,3574 11~,3750 637'~250 , 000 IL. DRHO GR DEPT SP NCNb C2 6500 t24 2394 -999 0000 SFLU 0000 OR 312,5 CALI 0000 FCNb 2500 2 8867 10, 406 622, ~000 NPH! DRHO G~ DEPT SP GR NCNb C2 6.400, 32, 70, 999, 0000 SFLU 10 7813 GR 7~ 1875 CALI 0000 FCNI~ 829 2500 IbM )0 GR DEPT 6300 2244 0000 SFLU 000 FCNb .500 1.4385 !b~ I1~,0000 NPHI ,4375 DRHO 577~0000 GR DEPT NCNb C2 6200 -51 13.4 ~0~6 0000 SFbU 3.1289 3125 GR 134, 2500 CALl 0000 FCNL 53],0000 GR 2500 1,9658 ILD 43.70i2 RHOB 0,0103 NRAT '99g,2500 C1 2,2266 ILD 47,5586 RHOB 0,0444 NRAT -999,2500 C1 2,5313 IhD 4~,6777 RHOB ,0620 NRaT -999,~500 Cl 2,1914 ILD 37,5000 RHOB 0,0186 NRAT -999,2500 C1 2.8418 41,4063 RHOB 0,0~0~ NRAT -999,~500 CI 2,5098 2~,6094RH08 ,0728 NRAT -999,2500 C1 1,4404 IbD 4~,5293 RHOB ,00i0 NRAT -999'2500 CI 2,8906 ILD · ,0273 NRAr -999,2500 C! 1,881.8 2,3027 3,62R9 -999,2500 2.3281 2.3867 3.6484 -999.2500 2.1406 2 3965 3i8203 -999 2500 2,4727 ,4238 ,7129 -999,2500 2,0723 ~,3828 ,2598 -999,2500 . 4746 -9992s176~500 2 ,2148 ,,999 ,0 1,4844 2,2988 3,5234 -999,2500 -099.2500 LVP OIO,HO1 VERIF!CATIOt~ I,ISTING PAGE DEPT 61()0,0000 SMLU SP -37.03!3 GR GR !46 1250 CALl NCNb 2140i0000 FC~B C2 -999 250o 1,7100 YLM 146,~250 NPHI 9,9922 DRHO 547,0000 GR 1.9648 41,4551 0,0132 NRAT -gg9,2500 C1 OEPT 6000 8P -30 GR 180 NCNb 2136 C2 -999 0000 SFLU ! 2070 6406 GR 180:8750 NPHI 8750 CALl 9~ 2734 DRHO 0000 FCNL 502,0000 GR 2500 !,528] ILD 42,4316 RHOB 0,0000 NRAT -999,2500 C1 OEPT 5900 SP -29 GR 184 NCNb 23!4 C2 -999 0000 SFLU ~,12B9 ILW 2969 GR 184 0000 NPH! 0000 CALI 9:6797 DRHO 0000 FCNL 582~ 5000 GR 2500 1,9062 41,3574 RHOB '0 0024 NRAT -999:2500 CI DEPT 5.80O NCNL 2160 C~ -999 oooo sF~u 2 5o59 :7344 GR 87:8750 [~PHI , 8750 CALI 9, 7]44 DRHO ,0000 FCNL 622,0000 ,2500 2,310~ ILD 36,3770 RHOB 0,0278 NRAT -999.2500 C1 DEPT 5700 SP -31 GR 76 NCNL 2276 C2 -999 0000 SFLU 2 0059 CALI 9,7578 DRHO 0000 FCNL 6]0,5000 GR 2500 2.0410 IbD 37.0605 RHOB 0,0605 NRAT -999,2500 C~ DEPT 5600 SP -34 G~ 98 .~CNL ~268. C2 qgg ,0000 SFLU 2.7188 ,2500 GR 98,0625 NPHI .0625 CALI '9,8984 DRHO ,0000 FCNL 745.0000 GR ,2500 2,9062 ILD ]0,1758 I~HOS 0;0220 NRAT .,.999,2500 C1 DEPT 55O0 ~C~L ~4~4 C2 999 ,0000 SFLU 3,0684 ,ILV ,6875 GR 103,1250 NPH! ,1250 CALl 9,6563 DRHO ,0000 FCNb 713,0000 GR ,2500 3,0195 35,9375 NHOB 0~048.~ 'NRAT -999.2500 Cl OEPT 5400, S ',35, G~ 86' NCN.L ~480, C2 999; 0000 SFLU 2,6953 ILM 2, 0000 GR 86~8750 NPH! 37, 8750 CAbI 9,7578 DRHO O, 0000 FCNL 67~.5000 ~R -999, 2500 ,D 2500 Cl DEPT 5300 SP '31, ~R I05: NCNb ~390 c~ ,,,~9 0000 SFLU 2 3027 IL~ 2,4I 80 0313 GR 0625 NPHI 38,8.184 RHOB 0625 CALI 2031 DRHO 0 ,0068 N~AT 0000 FCNL 646.0000 GR ,.999,2500 C1 2500 1,9521 2,3672 3,5098 -999,2500 ,697~ ,2930 3,5039 -999,2500 1,9111 2,3242 3,4785 -999,2500 2,2813 2,3320 3,2070 -999,2500 2,0117 2,3652 3,2461 -999,2500 2,9141 ,3418 ,8672 -999,2500 3,0352 ,'3652 "999,2500 2, "'999,~500 2 ,.999 ,2500 I,,~ OIO,HO! VERIFICAT!ON LISTING PAGE 9 DEFT 5200.0000 SFLU SP -27,4844 GR GR 94,8125 CALl NCNL 2294,0000 FCNL C2 -999,2500 2,8759 ILM 94,8125 NPH! 9.!172 DRHO 6]0,0000 GR DEPT 5100,0000 SFLU SP -31 0156 GR c~ 80:5625 CALl NCN[. 2848,0000 FCNL C2 -999,~.500 2,6738 ISM 80,5625 NPH! 7,9297 DRHO 853,0000 GR DEFT 5000 SP -37 GR 86 NCNL 2194 C~ -999 0000 SFLU 0313 GR 7500 CALI 0000 FCNL 2500 2.9648 86 7500 NPHI 8i5781 DRHO 569 0000 DEFT 4900 Sp -43 GD 89 NCNL 2304 C2 -999 0000 SFLU 5313 GR 7500 CALl 0000 FCN[. 2500 3.0605 It.N 89,7500 NPH! 7,6563 DRHD 616,5000 GR DEFT 4800 SP -41 NCNL 2268 0000 SFLU 3750 GR. 2500 CALl 0000 FCNL 25OO 2,6484 IbM 88,2500 NPH! 7,6758 DRHO 653,0000 GR 5,9766 IbM .2500 NPH ,6875 DRHC~ 759,5000 GR OEPT 4600 SP ,45 G~ tO7 ~CNL ~072 C~ 999 0000 SFLU 7813 GR 8750 CALl 0000 FCNL 2500 2,7090 !L~ 1..0~8750 NPHI ,,6680 578,0000 DEPT 450O .,4o gO -99g 0000 SFLU 2,9062 IL~ 281] GR 90,1250 NPH. I 1250 CALl 7,6680 DRH 0000 FCNL 464.,0000 GR 2500 O~iPT 4.400 SP '40 GR 90 NCNL 2013 c~ -999 0000 SFLU 2,4844 0000 GR 89, 2500 CALl[ ti, 0000 FCNL 493,5000 2500 2.g941 ILD 3,0547 38,5742 RHOB 2,2988 0,0034 NRAT 3,279~ -999,2500 C1 -999,2500 3,1875 ILD 3,1348 37 0605 {{HOB 2,1562 0~1201 NRA? 3,0957 -999,2500 C1 -999,2500 3,0~40 {LD 3.t660. 43,3594 RHOB 2,1055 '0,1t57 N~AT 3,5000 -999,2500 CI -999,2500 3.0605 ILD 3,1543 37.9395 RHOB 2,1094 0,0967 NRAT -999,~500 C1 -999, 500 2.8535 ILD 2,9414 0,0840 NR .~ 3, 8 '999,2500 C1 ..999,2500 .5527 IbD 3,3789 · 1479 NRAT ,8086 -999,2500 CI ,999,2500 3,7305 ,,999,2500 2, ! ) ILD 3 ;45 ,,999 2500 C1 -999 ,2500 2.5859 ILD 2,6738 ~3'603$ RHOB 2,2246 ".0 ~ 0005 NRAT 3 , 6992 -999,2500 Cl ,,999,2500 DVP 010,H01 VERIFICATION LISTING PAGE 10 DEPT 4300,0000 SFLL! SP '40,0000 GR GR ~3.5000 CALl NCNL ~256,0000 FCNL C2 g99,2500 4,4648 IbM 80,0000 NPH! 10,7969 DRHO 619,5(300 GR 3,0R01 75,0000 NPHI 10,8906 DRHO 667,0000 GR OEPT 4100,0000 SFLU 5P -45,0000 GR GR 73,2500 CALl NCNb 3200,0000 FCNL C2 -099,2500 2,7539 IbM 84 0000 NPM1 10!8906 DRHO 894 0000 GR OEPT 4000 0000 SFLU o0oo GR SP '49:Qt75 CALl GR 77, NCNL 2136,0000 FCNL C2 -999,2500 4 8594 ILM 79,0000 NPH! 10,8750 DRHO 552,0000 GR D~PT 3900 SP -58 GR 67 NCNb 2274 C2 -999 0000 SFLU 16.2344 0000 GR 63~5000 NPHI 1875 CALl I 0,3359 DR,O 000 0 FCNL 605.0000 GR 2500 DEPT 3800 SP -55 GR 72 NCNb 2114 C2 -909 0000 SFLU 5,1562 IbM 3125 GR 72,6875 NP~I 6875 CALl 10,3125 DRHO 0000 FCNL 543,5000 GR 2500 DEPT 3ZOO SP 54 NCNb 21.12: 0000 SFLU 6,8906 I..LM 6875 GR 85,5000 NPHI 5000 C~LI t2,8750 DRHO 0000 FCNb 5:16.5000 GR 2500 DEPT 3600 SP -57 GR 70 CNL 191,5 2 -999 0000 SFLU 4,5391 1[,~ 0000 GR 70, 1250 CILI 10, 0000 FCNb 461,2500 OR 2500 DEPT 3500 sp NCNb 2314 C2 -999 0000 SFLU I0,2500 ILM 52,5625 NPHI 10,2578 DRMO 646,0000 GR 4,4688 ILD 37 6953 RHOB 0i0439 NRAT -999 ~500 C1 4,6133 2 2832 3i3613 -999 2500 3.5000 ILO 36.3281 RHOB 0.030~ NRAT '999,2500 C1 3.7891 ,2441 ,2871 -999,2500 3,5488 ILD 34.9121 RHOB 0 0166 NRAT -999: 5oo 4,1445 2 2090 3:2090 '999,2500 5.0195 ILD 40,4297 RHOB 0,048t NRAT -999,2500 C1 5 2 3 -999 3477 3262 5156 2500 10,4063 ILD 38,5742 RHOB 0,0063 NRAT '999,2500 C1 i0,7422 2,2051 3,3770 -999,2500 6,5313 ILD 36,7676 RHO[ 0,0488 NRAT '999,2500 C1 7,~750 -gg9,2500 0 -999 t914 ILD 3301 al{OB 0249 NRAT 2500 C1 ,5977 ,3125 3,4512 '999.2500 5. 3086 I.I,D 404,1406 RHOB ,0786 N'~AT '999,2500 Cl 5,7813 '999,2500 9 ,3047 ILD 9,1,406 -999 !500 Ct -999 :500 LVP OIO,HO1 VERIFICATION LISTING PAGE 11 DEPT 3400,0000 SFLU SP -74 4375 GR GR 40'0938 CALl NCNL 2034,0000 FCNL C2 -999,2500 34,2187 40 0938 467 5000 ILM NPHI DRHO GR DEPT 3300,0000 SFLU SP -~1,3058 GR GR 4,8437 CALI NCNL 2308,0000 FCNL C2 10,5469 179 3750 30i4063 13 6641 570,5000 ILM NPHI DRHO GR DEP? 3200,0000 SFLU SP -37 4711 GR GR 59i0938 CALl NCNL 2200 0000 FCNL C2 9 4922 11,4453 40,3750 582,5000 ILM NPHI DRHO GR DEPT 3 ! O0 SP GR 76 NCNL 2162 C2 9 0000 SFLU 7934 GR 5625 CALl 0000 FCNL 4922 !6 2656 37i8750 9 6016 564,5000 NPHI DRHO GR DEPT 3000 SP -13 GR 80 NCNL 1832 C2 9 0000 SFLU 5041 GR 2500 CALl 0000 FCNL 5O0O 6,4297 479,7500 NPHI DRHO GR. DEPT 2900 GR ~C~L 2480 C2 10 0000 SFLU 9835 GR 968'7 CALl 0000 FCNL 4922 10,5625 ILM 14~,9062 NPHI ,5547 DRMO 654 , 0000 DEPT 2800 SP -47 GR 42 0000 5,313 0938 0000 7422 SFLU 8,4844 XI....~M GR 73,6875 NPNI CA[,,I I0,0859 D~O FCNL 327,7500 GR DEPT 2700 SP -66 CNb 1634 ~ ~0 0000 5FLU 0625 GR 5938 CALl 0000 FCNL 8672 24 ,2969 36 10 451, 2500 D.F..PT 2600 SP OR -999 ~NL -999 -999 0000 SFLU 2500 2500 22 t250 I!.~ 49,3750 NPHI '999,2500 DRHO -999,2500 GR 34,6875 ILD 47,2168 RHOB 0 0195 NRAT -. 99: soo 49,8437 ILD 43,6523 RHOB O,Olg5 NRAT 34,2187 Cl 10.!719 ILD 45.4102 RHOB 0,0142 NRAT 40.2187 C1 12.3750 XLD 42,6270 RHOB 0,0015 NRAT 37,9062 C1 6,2227 ILD 43.115~ RHOB 0,0269 NRAT 69,0625 C! 9.2344 ILD 39,7949 RHOB -0,0073 NRAT 48.4688 C1 7,6563 35 ILD B Cl 2! ,4375 ILD 4414 NRAT 25,171L9 Cl 14,2891 ILD '999,2500 [{HOB ". 999,2500 NRAT -999;2500 CI 39.0625 2 0117 3i8164 -ggg 2500 43,8125 ,1445 ].7676 10.5078 10,1719 2,1484 3,6738 9.!250 12:1797 1699 ~',5410 9,1250 6,1602 2,1602 3,6621 9,1875 9,7500 2,0879 ~,4648 ,2578 7 9844 ,24 0488 3477 9 7969 2i, 87 : i0,1406 13,2813 '999,2500 -999,2500 -999,2500 bVP OIO,HOI VERIFICATION LISTING PAGE 12 OEP? 2500,0000 SFLU SP -32 7813 GR, GR -999~2500 CALI NCNb -999 2500 FCNL C2 -999:2500 DEPT 2400.0000 SFLU SP 31 2969 GR 2500 c2 2 22soo . ooioooo s uu. SP 41 5625 GR GR 999 2500 CALl NCNL ..999,2500 FCNL C2 -999,2500 DEPT 2200.0000 SFhU $P -30,6094 GR GR -999,2500 CALl NCNb -999,2500 FCNL C2 -999.2500 D~PT 2100 SP -16 GR -999 NCNL -999 C2 -999 0000 SFLU 0938 GR 2500 CALl 2500 FCNL 2500 OEPT 2000,0000 SFLU ~{~ ,,.-24,0313 GR 999,2500 CALl NCNb -999,2500 FCNL C2 -999,2500 D£PT 19,00 $P '21 GR -999 NCNb ]999 C2 999 0000 SFLU 5'18 ! GR 2500 CAI,,! 2500 FCNL 2500 DEP? 1,800 $P -32 GR -999 CNL ~999 2 -999 0000 SFLO 2500 FCNL 2500 ,p DE..T 1700 GR '999 NCNb ~999 C2 999 0000 SFLU 2500 FCNL 25OO 19,2500 It, M 48.2813 NPH1 -999,2500 GR 14.0625 IL~ 58,96~7 -999,2500 DRHO -999,2500 GR 17.5156 IbM 46,5625 NPHI -999,~500 DRHO -999,2500 GR 9 5625 IbM 49:2500 NPHI -999.~500 -999.2500 GR 26.8594 IbM 47,9375 NPHI '999,2500 DRHO -999.2500 GR ,9!~,5625 ILM ,0625 NPHI ,2500 DRHO -999'2500 G~ 10 1484 IbM 88 999 -999 2500 GR 54,7188 IbM -999, -999,2500 36.4688 61,2813 NPHI -999,2500 -999.2500 GR 14.7891 ILD 15.5234 -999 2500 RHOB -999,2500 -999:2500 NRAT -999.2500 -999,2500 C 1 -999. 2500 18.4219 IbD 19 7188 -999,225500 RHO8 -999:..2500 ,999. O0 NRAT -999 2500 -999.2500 Cl ,,999 2500 12,9062 ILD 13.6250 999,2500 RHOB -999,~500 -999.2500 NRAT -999, 500 -999,2500 C1 '999,2500 22.0938 ][,D 22 4063 -999,2500 RHOB -999:2500 -999,2500 NRAT -999,2500 -999.2500 C1 -999.2500 12.2969 ILD 13,~109 999,2500 RHOB -999, 500 R ' 999'2500 N..AI -999, 500 999'2500 C1 -999,2500 9,9609 ILD 11,3438 ]999,2500 RHOB -999'2500 999,2500 NRAT :999,2500 -999.~500 C! 999,2500 54.4375 ILD '999,2500 RHOB '99'9,~500 NEA~ '999,~500 C1 62,1250 -999,2500 '999,2500 '999,2500 625O 31,6250 ILD 34,~500 '"999,2500 RHOB "999, '999' 2500 NRAT '999, ~500 · '999'2500 C.1 "999,2500 GVP OlO,HO1 VERIFICATION LISTING PAGE 13 DEPT 1.600! SP -29 GR 999 NCNb -999. C2 -999. OEPT 1.500 SP 37: GR -999. NCNb -999, C2 -999, DEPT 1400 SP GR -999 NCNL -999 C2 -999 OEPT 1.100i SP 38 GR 999 NCNb ,,,999. C2 -999. DEPT 1200 SP -42 GR -999 NCNb -999 C2 -999 DEPT ~100, SP -4.7. GR 99g. NCNL -9g~, C~ -99g. DEPT 1~00, SP 52, GR. '999' NCNU -999. C2 -999. DEPT 900 P '54 R -999 NCNL -999 C2 -999 OEPT 80O -999 N NJ, '9 C~ 99 -999 0000 SFbU 295,7500 lbM 0469 GR 47,7188 NPHI 2500 CALl -999.2500 DRHO 2500 FCNL -999.~500 GE 2500 146 3750 IbD -999i2500 RHOB -999 2500 NRAT -999.2500 285.7500 -999,2500 -999.2500 -999,2500 0000 ~FLU 847 0000 XLM 5313 GR 43i3438 NPHI 2500 CALI -999 2500 DRHO 500 FCNU -999.2500 GR ~500 245.5000 ILD -999,2500 RHOB '999,2500 NRAT -999.2500 C1 456 2500 -999:2500 -999.2500 -999.2500 0000 SFLU 128 5000 5625 GR 65!2500 NPHI 2500 CALI -999 2500 DRHO 2500 FCNb -999,2500 2500 75.5000 '999.2500 RHOB ..999 2500 NRAT .999:25oo !03,9375 -999,2500 -999.2500 -999.2500 0000 SFLU 44 0938 IbM 5938 GR 77:1250 NPHI 2500 CALl '999. 2500 DRHO 2500 FCNL -999,2500 GR 250O 40,031] ILD -999,2500 RHOB '999.2500 NRAT -999,2500 C1 50,8750 -999,2500 -999.2500 -999.2500 0000 SFLU ]5,5625 IbM 0313 GR 77,1875 NPHI 2500 CALI -999.2500 DRHO 2500 FCNU -999.2500 GR 2500 3~,656] ILD '999,2500 RHO8 '999.2500 NRAT '999.2500 C1 45,281~ '999,2500 '999,2500 '999,2500 0000 SFLU 77,7500 ILM GR . 55'2813 NPH 2500 R 25 CALI ~999, D Mi) 2500 FCNL 999,2500 GR 2500 72,7500 -999,2500 RHOB ~999,2500 NRAT .999,2500 I O5 0000 25oo 999 2500 -999 2500 0000 SFLU 36,2500 IbM 78.1003 GR 80, 25. CALI -g99, 2500 FCNb -999,2500 GR 2500 36.0313 IUD -999 500 Clr 44,6250 -99~'~500 '999.2500 -999.2500 0000 SFLU 70,3 ,~ 34,5313 IUD 45,6875 0313 GR 68,6~ , NPH! ,,ggg.2500 RHOB -999,2500 2500 CALX -999'~ ~ DRHO '999,~500 NRA% -999,2500 2500 FCNL -999"2500 G'R -99912500 CI -999,2500 2500 0000 8FLU 3125 2500 2500 FCNI, 2500 538.0000 I!L~ ~3,0000 NPHI .999;2500DRHO 999;2500 GR 1.83,3750 ILD 368,5000 '999,2500 RBOB -999,:2500 ,2500 -999 bVP 010,H01 VERIFICATION LISTING PAGE 14 DEPT 700. GR -999. NCNL -999. C2 -99g. DEPT bO0. SP GR -999, NCNb -999 C2 -999: DEPT 500. SP -19. GR -999, NCNb '999, C~ -999, DEPT ~00, SP 31, GR -999, NCNL -999, C2 -999, DEPT ]00 Sp -38 G~ -999 NCNb -999 C2 -999 0000 SYL{} 2500 CALl 2500 FCNL 2500 0000 SFLU 6250 GR 2500 CALl 2500 FCNL 2500 0000 SFLU 0313 GR 2500 CALl 2500 FCNL 2500 0000 SFI,U 6719 GR 2500 CALl 2500 FCNb 2500 0000 S~LU 7500 GR 2500 CAL! 2500 FCNL 2500 0000 SFLU DEPT 200:7188 GR GR - ,2§00 CALI NCNb -999 2500 FCNL C~ -999:~500 OEPT 106 SP 11 OR -999 NCNb -999 C2 -999 0000 50 0 500 5OO 8FLU GR AbICNb 190.6250 ILM 45.6875 NPHI -999.2500 -999.2500 GR !7g,1250 ILg 71 0625 NPHi -999:25oo -999,~500 GR 140.7500 !bM 67,6875 NPH! -999,2500 D~HO -999,2500 GR 211.1250 53,1250 NPHI '999'2500 DRNO '999.2500 GR 394.5000 IbM 34]8 N.PHI '999:2500 DRHO '999.2500 GR q3 8125 ]9 8125 NPHI -999 2500 DRHO -999 ~500 GE 0,4023 27,4063 NPH] -999, ~500 D~HO ,,999,2500 GR 111,0625 ILD -999.2500 RMOB -999,2500 NRAT -999.2500 C1 44.0000 !bD -999,2500 RHOB -999'2500 NRAT -999,2500 Cl 53 8437 -999i2500 RHOB -999 2500 NRAT -999.2500 C! 96,3125 ILD '999.2500 RHOB '999.2500 NRAT -999'2500 Cl 37,7813 ILD -999 2500 RMOB -999~2500 NRAT -999.2500 CI 17,0156 -999,2500 RMOB -999,2500 NRAT -999.2500 Ci 0,8599 ILD '999, -999, '999,2500 C! 212,2500 :999.2500 999.2500 ,.999,2500 88,5000 -999,2500 -999,2500 -999,2500 153,3750 -999,2500 -999,2500 -999,2500 318,2500 -999.2500 -999,2500 -999,2500 124 5625 -999:~500 -999, 500 -999,2500 41 8437 -999 ~500 ,.999 500 -999 2500 000,0000 999,2500 ,,999,~500 -999'2500 SERVICE NA~E '. V~R$I 1 ' ' IN # · DATE : MAXIMUM b~NGTH : FILE TYPE NEXT FILE 1024 EOF bVP O!O,HO1 VERIF'IC~TION I,ISTING PAGE 15 ** TAPE TRAILER ** SERVICE NA~E :$ERVIC DATE ORIGIM ~APE ~A~E 565433 CONTINUATION ~ NEXT TAPE NAME COMMENT8 :TAPE COMMENTS ** REEL TRAILER ** SERVICE NAME :SERVIC O~TE 582/08/13 REEL NAME SREEL ID CONTINUATION # ~01 NEXT REEL NAME : COMMENTS :REEL COMMENTS ********** EOF ********** ********** EOF **********