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183-051
• • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: Wednesday,July 12,2017 P.I.Supervisor �� �� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1Y-10 FROM: Adam Earl KUPARUK RIV UNIT I Y-10 Petroleum Inspector Src: Inspector Reviewed By7, P.I.Supry v'-"— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-10 API Well Number 50-029-20934-00-00 Inspector Name: Adam Earl Permit Number: 183-051-0 Inspection Date: 7/7/2017 Insp Num: mitAGE170708065511 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Y-10 1Type Inj N TVD 4557 " Tubing 790 2790 ' 2610 " 2585 PTD 1830510 Type Test SPT Test psi 2500 - IA 925 • 1000 _ 1020 - 1020 • BBL Pumped: j 0.8 ' BBL Returned: I2 - OA 40 40 - 41 41 Interval REQVAR P/F P Notes: MITT against plug set below packer at 6870ft.As per AIO 2C.014 SCANNED SEP 2 5 2017, Wednesday,July 12,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,July 12,2017 TO: Jim Regg P.I.Supervisor l .71161(7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1Y-10 FROM: Adam Earl KUPARUK RIV UNIT 1Y-10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IY-10 API Well Number 50-029-20934-00-00 Inspector Name: Adam Earl Permit Number: 183-051-0 Inspection Date: 7/7/2017 Insp Num: mitAGE170708065059 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IY-10 Type Inj N 'ITVD 4557 ' Tubing 875 - 1090 - 1125 - 1125 PTD 1830510 ' Type Test SPT Test psi 3000 IA 950 3300 - 3200 e 3190 BBL Pumped: 1.4 BBL Returned: 1.3 OA 41 - 41 41 - 41- Interval REQVAR 'P/F P ✓ Notes: MIT IA as per AIO 2C,014 SCANNED SES' 2 5 241? Wednesday,July 12,2017 Page 1 of 1 • I COcu �0 N X. 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Q D) O) d) 6) 6) O) Q) c�) O) Q) 6) 6) d 0 p N NNN NNNONNNN L O1 0000000 3 0 0 0 0 0 0 0 0 0 0 0 6a, 0 a L 4 c v) 1() v) u) u) u) u) In u) u) It) N a u d7 µ°ii In a) as a) CID i FE a CC cC aa uvag a Q _ O O O O CO CON OF' dO co O CO CO CO O ,�+ a 3 dv) d e = b 00 z _ M+ H • II u ^ w N N N M N N VI C z BVI Y C *' fp v, .0▪ �" N ri C ((0 .� GJ t0 0 y O. al Q I- a a Q • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday, May 16, 2017 7:56 PM To: Wallace, Chris D (DOA) Cc: NSK Well Integrity Supv CPF1 and 2; Senden, R.Tyler Subject: KRU injection well 1Y-10 (PTD#183-051) Report of WFL up flow indications Attachments: 1Y-10 90 day TIO trend 5-16-17.JPG; 1Y-10 wellbore schematic.pdf;CPAI_1Y-10_IPROF- WFL_28-MAR-2017_Processed_Report.pdf; CPAI_1Y-10_RST-WFL_28-APR-2017 _Processed_Report.pdf Chris, Kuparuk injection well 1Y-10(PTD#183-051) is regulated by AIO 2C.014 which requires CPAI to perform a Pulse Neutron Log every 2 years. On March 28th, 2017 a Water Flow Log(WFL)was performed and reported up flow from multiple station stops at various depths. The data from the WFL was questionable as the up flow velocities observed were at the low end of the tool's velocity range. A 2nd WFL was requested to gather more data. On April 28th, 2017 the 2"d WFL was performed and it also reported up flow from multiple station stops at various depths. Operations has been contacted and they will shut the well in as soon as possible. The plan at this point is to set a tubing plug to perform an MIT-T and MIT-IA(also requirements of AIO 2C.014)and secure the well while a path forward is determined. Once a plan has been developed a follow up email and any required paperwork for corrective action or continued injection will be submitted. A wellbore schematic,90 day TIO trend and WFLs are attached. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne Well Integrity Projects ConocoPhillips Alaska, Inc. Desk Phone(907)659-7891 SCANNED ,r-Lb E.B 2 i2.0! 411;IrLLS TEAM norcaPhaipa 1 r In M • 0 a L x • co rcJ a o > EN 3 (O a) L •O O oo � '13 > _( n r0 µ- 10 03 cc ..YE a III ,..5 a` a v o o 4. @ o v aCO Q J Ow w L u a c Q Q5 p ,14 r ' - � N aJ E Oa - m C L L 'p Q O N w O co coW co to ` vo O N t/1 4 Y tD IZ• 8 Q) a3 o C ro u L QJ ^N Zr a N N N N O 4-' c z < 0 i >2 G. v E \-c a)u . F- O c L +O u 0 0 4., c O 1Z3 v, LY a >• J J J J pOCO cp v 0O W W W W "" U 42 V (1, .`- c H LL LL LL LL C a J J J J a D > L a) u I- Q Q Q QYO µ- G r. Qq Z Z Z _Z u r`no C " C O �; LL LL LL LL a) L a) �, v 1 «1G .,... cC c > la' o Y a1 +�+ a) o_▪ c ID C E e " a ✓ a v u 1,-• • c O tiµ > f13 4: 63 - G C aJ - 0 -c c a .� 4 ~ c c a o 0 co >� G < a) a .n c a Ir E !. C - _ a LL O 1.1 V U m 2,��^^ a) <v 0 V } • (B — d i" iti to 0 d 0 o G RS t0 u.i • _d co _y S�RI ? �,.. - 0. J J J J Z , W W W W > > > > 4014 ... OMD Y Y Y Y IX CC X ce Ca Q Q Q Q v vl o a a a. a O 0 cc Y Y Y Y ILLI c i- 1%. oA O Nw O o r- N X Lii 0 0 r 0 5 0 0 0 0 W CO '..�/ 0 0 0 0 0 0 0 0 0 aJ C u . fn N fn r f6 00 Q.. W 0 0 0 0 Q c LU a Q g ,,+ u s CC 8 o 0 0 0 0 _ O O O 0 " 0 f0 1 CO CO Of O) +� _ fl N N N O N c – N N N N N E S S C rn N N N c o a N 0 0 N O O O O a7 u O z c _a -0 o C co Q! Lrl f0 u c , 0 RE a) � � aIQQ� , c vE E Z '` Z N N = a Q 0 J E m a) v s .0 , r ^ '., z N O O .c C2 P V cu Q1 3 = y E E I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,September 08,2016 TO: Jim Regg P.I.Supervisor .eICt. 611 Pie(' SUBJECT: Mechanical Integrity Tests (( CONOCOPHILLIPS ALASKA INC 1Y-10 FROM: Johnnie Hill KUPARUK RIV UNIT 1Y-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-10 API Well Number 50-029-20934-00-00 Inspector Name: Johnnie Hill Permit Number: 183-051-0 Inspection Date: 8/18/2016 Insp Num: mitJWH160818184357 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IY-lo Type Inj N' TVD 4557 Tubing 1250 1500 1540- 1540 PTD 1830510 - Type Test SPT Test psi 3000 , IA 340 3300 3200 " 3180 Interval REQ VAR P/F P ✓ OA 34 - 34 34 34 Notes: 1.4bbls of diesel used.MITIA per AIO 2C.014 SCANNED :.IUN 2 12c117 Thursday,September 08,2016 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / DATE: Thursday,September 08,2016 P.I.Supervisor �Al( 1(14 tiL-; SUBJECT: Mechanical Integrity Tests C CONOCOPHILLIPS ALASKA INC 1Y-10 FROM: Johnnie Hill KUPARUK RIV UNIT 1Y-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry a4-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-10 API Well Number 50-029-20934-00-00 Inspector Name: Johnnie Hill Permit Number: 183-051-0 Inspection Date: 8/18/2016 Insp Num: mitJWH160818184131 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Y-10 ' Type Inj 1`1. 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A CJS z O N O O N O Y E cu 0.1 CU 1 Noma d Q Oh SLQ N J m C) M CJ VI M ,- N E z v O O M1 C c_ c Y� V .-I ca E E p cop d 1 H a a F H • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,October 20,2015 TO: Jim Regg '1 c, 1013011G P.I.Supervisor ' \ ( l SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Y-10 FROM: Bob Noble KUPARUK RIV UNIT IY-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JSP-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-10 API Well Number 50-029-20934-00-00 Inspector Name: Bob Noble Permit Number: 183-051-0 Inspection Date: 8/27/2015 Insp Num: mitRCNI51015165644 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well l IY-10 - Type Inj N 1TVD 4557- Tubing 40 3300 PTD I 1830510 - Type Test SPT Test psi; 1500 - IA 11 1 II Interval REQVAR P/F F OA I 33 33 Notes: The plug failed to hold pressure. SCANNER ' ; Tuesday,October 20,2015 Page 1 of 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,September 16,2015 Jim Regg P.I.Supervisor ��) ei - CSI/� SUBJECT: Mechanical Integrity Tests C(f CONOCOPHILLIPS ALASKA INC 1Y-10 FROM: Chuck Scheve KUPARUK RIV UNIT IY-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JB/2-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-10 API Well Number 50-029-20934-00-00 Inspector Name: Chuck Scheve Permit Number: 183-051-0 Inspection Date: 9/12/2015 Insp Num: mitCS150913072820 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Ir IY-10 Type Ind N TVD 4557 Tubings 650 I 2500 - 2370 - 2340 PTD I 1830510 Type Test SPT Test psi 1500 - IA 43 43 - 43 - 43 • Interval 'QVAR P/F P ✓ OA 29 29 - 29 - 29 Notes: MIT-T as required by AIO 2C0.14 ARE Wednesday,September 16,2015 Page I of 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, August 28, 2015 4:25 PM To: Wallace, Chris D (DOA); Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Senden, R. Tyler; NSK Problem Well Supv Subject: KRU 1Y-10 (PTD 183-051) Report of failed MITT Attachments: 1Y-10 schematic.pdf; MIT KRU 1Y-10 Plug test 08-26-15.xls Chris,Jim Kuparuk injector 1Y-10(PTD 183-051)failed a witnessed MITT. As per AIO 2C.014, a tubing plug was set to perform the MITT and when initially set a passing test was achieved (see attached form). It appears that the plug began leaking resulting in the failing test. Slickline will pull the plug and reset a new one and test. Once the new plug has been set, a witnessed test will be rescheduled. The MIT anniversary date is 08/29/14. With the suspected failure of the plug, it will delay the testing until after the anniversary date. The well will remain shut in until the well work to pull and reset the plug and a passing MITT has been achieved. There is a rig that may be blocking access to the well for a Slickline unit so there may be a little delay in getting the plug pulled and reset. Please let me know if you have any questions. Also attached is a wellbore schematic and 90 day TIO plot. Well Name 1Y-10 Notes: Start Date 5/3012015 Days 90 End Date 8128/2015 2ECC - — 1E[ 6'JHP Annular Communication Surveillance IAP OAR -.v, — 141 WHT J Y 2CCC — 121 — 121 1=00 111 — 1Ci , 1000 j 901i Q. — 8C =00 ,C .5 l'ay-1E I'at'-1E Jun-15 Jun-15 Jun-15 Jul-15 Jul-15 Jul-15 Aug-1E xug-1E +aug-1E Sep-15 e::: -wwwwwww Ilay-15 May-15 Jun-15 Jun-15 Jun-1E Jul-15 Jul-15 Jul-15 Aug-15 Aug-15 Aug-15 Sep-15 Date Brent Rogers I Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907) 659-7000 pgr. 909 2 kt3-051 25�q-1 WELL LOG TRANSMITTAL DATA LOGGED 5 in/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. April 29, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAY 0 6 2015 AOGCC RE: Leak Detect Log with TMD3D: 1Y-10 Run Date: 4/26/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1Y-10 Digital Data in LAS format, Digital Log file 1 CD Rom 50-029-20934-00 SCANNED JUN 1 5 2015 Leak Detect Log with TMD3D (Field print) 1 Color Log 50-029-20934-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 6-4A-est MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg C,,�<7 4(3a I IS DATE: Thursday,April 30,2015 P.I.Supervisor (/ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Y-10 FROM: Bob Noble KUPARUK RIV UNIT IY-l0 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-10 API Well Number 50-029-20934-00-00 Inspector Name: Bob Noble Permit Number: 183-051-0 Inspection Date: 4/24/2015 Insp Num: miLRCN150424172058 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 7 Well 1Y-1° 'Type Inj W 1TVD 4557 Tubingi 1150 1150 • 1150 - 1150 • PTD 1830510 Type Test SPT Test psi 2600 - IA i 240 2910 - 2800 - 2785 ' Inter INITAL P/F 30 - 30 -P OA 30 30 - Intervaall ) Notes: MIT-IA every 2 years to the max antiipated injection pressure Max pressure is 2600 psi Post workover k ZC SOWED MAY 2 2 2015 Thursday,April 30,2015 Page 1 of 1 Wallace, Chris D (DOA) From: NSK DHD Field Supervisor <NSKDHDFieldSupervisor@conocophillips.com> Sent: Tuesday, February 10, 2015 8:26 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv Subject: FW: Kuparuk injector 1Y-10 (PTD# 1830510) Attachments: MIT KRU 1Y-10 Nordic3 Charted 08.29.14.xls Mr. Wallace, Attached is a copy of the rig chart information transferred to an AOGCC MIT form for 1Y-10 (PTD#1830510) per your request. Let us know if there is any question or other information needed. Respectfully, Roger Mouser/Bruce Richwine CPAI DHD Field Supervisor ForE�j q!, Jan Byrne/Dusty Freeborn ��� Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7126 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Friday, February 06, 2015 3:50 PM To: NSK Problem Well Supv Subject: [EXTERNAL]Kuparuk injector 1Y-10 (PTD# 1830510) Jan, We are • •gressing the AA for this well and note the MITIA charted on August 29, 2014. This is a non-standard and non- witnessed to but for the AA we can couple it with the MITT and progress. What I need thou:• is for you to transcribe the rig chart onto the AOGCC MIT form and submit so we have the record in our database. Let me know if any questions or •ncerns. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains in mation from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole se of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized revie , use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, 1 PTJ) /F3- z) 5--/ Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday,January 27, 2015 10:55 AM To: Wallace, Chris D (DOA) Subject: FW: 1Y-10 (PTD 183-051, Sundry 314-285) Attachments: 1Y-10 Schematic(1-26-15).pdf Chris, A request for AA for this well for water only injection will be coming in soon. I have some history so we can discuss. Just wanted to give you a heads up. It's a bit of a mess. Let me know when you get the AA request and if you want to discuss Thanx, Victoria From: Packer, J.Brett [mailto:J.Brett.Packer@conocophillips.com] Sent: Monday, January 26, 2015 3:02 PM To: Loepp,Victoria T(DOA) Subject: 1Y-10 (PTD 183-051, Sundry 314-285) SCAtito Dear Ms. Loepp, The purpose of this letter is to notify the AOGCC of changes that occurred during the course of a Rig Workover on (RWO) on ConocoPhillips KRU Injection well 1Y-10 (PTD 183-051, Sundry 314-285). The AOGCC was notified throughout the RWO of the changes and a 10-404 has been submitted, but due to resultant atypical completion, we felt it would be appropriate to summarize the current well condition and future operating intentions. The original RWO objective was to pull the tubing, stretch the 7" production casing, mill and pull the upper packer and selective tubing completion down to lower the packer and then run a new 3 '''A" x 2 %" selective completion. After the tubing was pulled during the RWO significant amounts of helical buckling were revealed in the 7" production casing. At that time ConocoPhillips determined the best plan forward was to perform a full subsidence RWO before milling and pulling the upper packer and selective tubing completion. As part of the full subsidence work the 7" production casing above the top of cement(TOC)was replaced and cemented to surface within the surface casing. After completing the subsidence portion of the RWO and removing the upper packer, there were several unsuccessful attempts to fish the remaining 252' of 2 34"tubing on top of the lower packer at 9118'. The decision was then made to just complete the 1Y-10 well "as is" with a tubing tail above the fish and return the well to injection. Acknowledging there would be no selectivity in the "as is" completion, we were able to leave out the planned injection mandrels below the new packer which allowed the packer to be set at 6870' MD,218' deeper than the original procedure. After the packer was set, the tubing pressure test passed, however a passing production casing pressure test was not achieved. Prior to the RWO the 7" production casing passed an MIT-IA to 3,000 psi on 5/16/13 down to the original packer depth of 6652' MD, therefore, we suspected there was either a 7" producing casing leak between 6652'-6870' MD,or the Premier packer itself was not holding. A test packer determined competent production casing above 4670' MD however,could not confirm if there was packer or an additional casing leak lower. The newly discovered 7" production casing leak near 4670' corresponds to the West Sak Al sand from the well log. There were two feasible options to isolate the leak behind pipe: run a kill string and secure the well for a future workover or stack a packer above the leak. 1 The decision was made to stack a packer at 4556' MD with 2 gas lift mandrels as part of the completion that allows the option to attempt a sealant or cement leak repair at a later date. The well subsequently passed a 30 minute 3000 psi production casing pressure test and a 15 min 3500 psi tubing pressure test before the rig was released. To confirm the integrity of the Premier packer set at 6870', Pulse Neutron Log (PNL) diagnostics were completed post- RWO. A plug was set just below the Premier packer and two PNLs were run while pumping through an open mandrel between the upper FHL packer set at 4556' and lower Premier packer at 6870'. The logging tools were oriented for down and then up flow fluid movement. Both runs confirmed that the Premier packer set at 6870' MD was competent. The logging runs also confirmed leaks in the 7" production casing between 6700'-6710',6720'-6730',and 6760'-6770'. Due to lack of compliance with AOGCC 20AAC.25.412 (b) "...The packer must be placed within 200 feet measured depth above the top of the perforations..." 1Y-10 has remained shut-in since the workover was completed. However, ConocoPhillips recently completed a risk assessment on 1Y-10 to document and categorize the likelihood and consequences of additional barrier failures on this atypical completion. The results of the risk assessment document a slightly higher risk profile than a normal well, however, with proper mitigations and compliance testing it should be acceptable for the well to be on water only injection. Therefore our Well Integrity Group will be applying for Administrative Approval to allow for water only injection with alternate packer and compliance criteria to account for depth of the top most packer and straddle packers across the known production casing leaks. I attached a copy of the current schematic for 1Y-10. If you have any questions or require any further information, please contact me at 265-6845. Sincerely, 5.Brett actor cThiing eft Was Supervising WonEQver Engineer Wort,# (907)265-6845 Cell# (907)980-9467 2 • F KUP INJ • 1Y-10 ConocoPhillips m Well Attributes rax Angle&MD TD ` Alaska,Inc Wellbore API/U1/61 Field Name Wellbore Status CI MD(RKB) Act Btm(RKB) (r not... " 500292093400 KUPARUK RIVER UNIT INJ 5820 4,000.00 10,115.0 I_ .-. Comment 112S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date 1Y-10,11/13201410.5206 AM SSSV:NIPPLE Last WO: 7/28/2014 35.01 4/15/1983 VertcOI schematic(actual) 'Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: 9,247.0 7/16/1999 Rev Reason:GLV CIO,PULLED RHC.SET lehallf 11/13/2014 HANGER;26APLUG P - 1 Caning Strings 1..___.. .._..._. _. 4. _ Casing Description OD(in) ID(in) Top(R(B) Set Depth(N(B) Set Depth MIDI_Wt/Len p...Grade Top Thread CONDUCTOR 16 15062 30.0 80.0 80.0 62.50 H-40 WELDED ,,,,,,,,,.,.�,.,,,,,,.,,�,,.,�..,,..,,,.�,a term utl Casing Description OD(in) ID(in) Top(ORB) Set Depth(R(B) Set Depth(TVD'...Wt/Len 11...Grade 'Yop Thread I SURFACE 9 5/8 8.835 29.3 2,726.9 2,200.7 40.00 J-55 BTC Casing Description 'OD(in) ID(in) top(RKB) set Depth(MO) Set Depth(TVD)...WVLen(I...Grade Top Thread PRODUCTION TIE- 7 6,276 294 1,245.0 1,206.7 26.00 L-80 TCII BACK .Mn CONDUCTOR,30.5 0.0.4A/�N s Casing Description 'OD(in) ID(in) Top(KK8) Set Depth(ftl(B) Set Depth(IW)...WtlLen(I...Grade Top Thread PRODUCTION/Post Tie 7 6.276 1,245.0 7,294.1 4,836.6 26.00 J-55 BTC Back NIPPLE;491.9 • - Casing Description SOD(in) ID lin) Top(1tKB) Set Depth 0003) Set Depth(TVD)...Wt/Len II...Grade Top Thread LINER ' 5 4.408 6,951.8 9,607.5 6,241.6 15.00 K-55 FL4S • Liner Details Nominal ID Top(ftKB) Top(TVD))BKB) Top Ind CI Item Des Corn (in) 6,951.8 4,612.6 47.50 HANGER BAKER LINER HANGER ASSEMBLY 4408 PRODUCTION TIE-BACK;29.4- /IL. 9,524.1 6,187.1 49.12 CATCHER BAKER CATCHER SUB 4.408 1,245.0 Tubing Strings Tubing Description String Ma...ID(in) Top(RKB) Set Depth(R..1 Set Depth'TVD)(...Wt(Ib/R) Grade Top Connection TUBING-Upper 31/2 2.992 264 6,846.2 4,541.5 9.30 L-80 8rd EUE SURFACE;2982,7268 .1 Completion Details --- Nominal ID ICE (RKB) Top(TVD)(NOB) Top Inc)(') Item Des Corn (in) GAS LIFT;4,477.5 26.4 26.4 0.06 HANGER TUBING HANGER 3.500 491.9 491.9 1.26 NIPPLE CAMCO DS NIPPLE 2875 4,533.0 3,169.6 57.77 LOCATOR 7LOCATOR SUB 2970 LOCATOR,4,533.0 i i 4534.0 3,170.1 57.77 SEAL ASSY BAKER 80/40 SEAL ASSEMBLY w/7ft space out 3.000 SEAL ASSY;4,534.0 4,556.4 3,182.1 57.79 PACKER BAKER FHL RETRIEVABLE PAKER 2.940 PACKER;4,556.6 6,820.6` 4,524.4 48.21 LOCATOR LOCATOR SUB 2.970 6,821.8 4,525.2 48.20 SEAL ASSY BAKER 80/40 SEAL ASSEMBLY w/2ft space out 3.000 rt Tubing Description String Ma...ID(in) Top(RKB) Set Depth IR..Set Depth(TVD)(...VA(Ibm) Grade Top Connection GAS OFT;5.704.1 ■ C TUBING-Lower 3 1/2 2 3/8 1.995 6,840.41 8,861.0 5,766.8 4.60 L-80 EUE x 23/8 @6936.9 Completion Details Nominal ID Top(KKB) Top(71/01(M03) Top Inel(') Item Des Com (in) 6,840.4 4,537.6 48.06 SBE BAKER 80/40 SEAL BORE RECEPTACLE 4.000 GAS LIFT,6,577.7 6,870.4 4,557.8 47.83 PACKER BAKER PREMIER PRODUCTION PACKER 2.880 6,925.6 4,594.9 47.55 NIPPLE CAMCO DS NIPPLE 2.812 6,937.0 4,602.6 47.53 XO-Reducing XO 3 1/2"x 2 3/8" 1.990 LOCATOR;8,820.5 i ` 8,860.5 5766.5 51.68 WLEG WIRELINE ENTRY GUIDE sitting 1ft above fish(4" 2.000 SEAL ASSY;8821.8 washpipe 8 decompletion string). SBE;6,840.4 _ Tubing Description 'String Mn...IID(In) (Top(RKB) -Set Depth(IL.J Set Depth((VD)(...I Wt(IBRO !Grade 'Top Connection TUBING-Original- 3 1.9951 8,862.2 9,145.51 5,943.5 2.375 OD PACKER;6.8704 Completion Details Nominal ID Top(RKB) Top(11/0)1N(B) Top Ind 1') BM Des Com (In) NIPPLE;6,9258 8,875.2 5,775.7 51.59 BLAST JTS 'STEEL BLAST JOINTS(8) 1.995 PLUG;8,926.0 9,117.2 5,925.9 51.48 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 1.968 9,118.2 5,926.5 51.47 PACKER BAKER 2 3/8'x S DB PACKER 2.600 9,121.2 5,928.4 51.46 SBE BAKER 40-26 SEAL BORE EXTENSION 1.995 7 1■r 9,132.2 5,935.2 51.43 NIPPLE CAMCO D NIPPLE NO GO 1.810 9,143.9 5,942.5 51.39 SOS BAKER SHEAR OUT SUB,ELME)TTL @ 9136'during 1.995 !PROF on 8/3/2007 PRODUCTION/Post Tie Back, Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 1,245.0-7,294.1 Top(TVD) Top Ind WLEG;8,860.5Top(R(B) (RKB) C) Des _ Com Run Date ID(in) 6,926.0 4,595.2 47.55 PLUG SET 2.81"CSA-2 PLUG 11/12/2014 8,868.0 5,771.2 51.63 PACKER ECLIPSE PACKER '12/20/2000 1.063 PACKER;8,888.0 Perforations&Slots - Shot Dens !PERF;8,872.0-9,004.0 Top(TVD) Btnn(TVD) (shots/f - Top(NOB) atm(RKB' (RKB) (KKB) Zone Date 0 Type Com 8,872.0 9,004.0 5773.7 5,855.6 C-4,C-3,C-2, 4/15/1983 4.0 IPERF 33/8"SOS HyperJet C-1,1Y-10 SEAL ASSY 9,117.2 PACKER;9,116.2 9,213.0 9,218.0 5985.7 5,988.9 A-5,1Y-10 4/15/1983 4.0 IPERF 338"SOS HyperJet SBE;9,121.2 9,234.0 9,262.0 5,999.0 6,016.7 A-4,1Y-10 4/15/1983 4.0 IPERF 33/8"SOS HyperJet 9,282.0 9,315.0 6,029.5 6,050.7 A-3,1Y-10 4/27/1983 4.0 (PERF 3 3/8"SOS HyperJet ' NIPPLE;9,132.2 Mandrel Inserts 50S;9.143.9 St ati on'PERF;9,213.08,2160 1 N Top(TVD( Valve Latch Pat Size TRO Run J Top(RKB) (R1(81 Make Model OD(in) Seen Type Type (in) (psi) Run Date Can 1 4,4775 3,140.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/11/2014 (PERF;923408,2820 1 2 5,704,1 3,824.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 8/29/2014 3 6,577.7 4,364.7 CAMCO KBMG 1 GAS LIFT OPEN BK-5 0.000 0.0 11/12/2014 I PERF;9,282.0.0,315.0 Notes:General&Safety End Date Annotation 10/1/1987 NOTE:WO 4/15/2006 NOTE:WAIVERED FOR OA x FORMATION COMMUNICATION LINER;895189.6075 KUP INJ 1Y-10 • ConocoPhillips • Alaska.Inc. conal alLpa ••' 131-10.11/13/2014 10:5207 AM Vertcal acnenubc(actual) HANGER;26.4 BI !P Notes:General&Safety .._..._............._...._........................__........{�. - End Data Annotation 8/24/2014 NOTE:ORIGINAL TUBING a@ 8862.2-9145.5 NOW A FISH DOWN HOLE .h.AA CONDUCTOR;30.0-800 NIPPLE;4919 PRODUCTION TIE-BACK;29.4- 1,2450 SURFACE;29.3-2,726.9--• GAS LIFT;4,477.5 1.1 LOCATOR;4,533.0 SEAL ASSY;4534.0 PACKER;4,558.4 GAS LIFT;5,704.1 IEE GAS LIFT;6,5777 II LOCATOR.6.820.5 SEAL ASSY;6,821.8 SBE;6,840.4 PACKER;6.870.4 NIPPLE;6,925.6 PLUG;6,9260 7 t PRODUCTIONIPoat Tw Bac; 1,245.0-7,294.1 VVLEG;8,8605 PACKER;8,868.0 IPERF;8,872.0-9,004.0 SEAL ASSY;9,117.2 PACKER;9,1182 SBE.9.121 2 NIPPLE;9,132.2 SOS;9,143.9 IPERF;9,213.0-9,2180 IPERF;9,234.0-9,262.0 -4 (PERF;9,282.0&,3150 LINER;6,951.86,6075 ~ge Project Well History FileOver Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~- S ~-' D -~] Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: -- Logs of various kinds NOTES: [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanning Preparation ,~ x30=¢~ BEVERLY BREN VINCENT SHERY m,_[~ LOWELL DATE: BY: Production Scanning Stage BY: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: .Is~ General Notes or Comments about this file: Quality Checked (do.e) 4..ma .3w l iarMiktt!i t.L.LUtbt - eta haat i..?.....�,mwrIMNI.�t",scrssVIZEIe.Sf. .�,..�aa's&"a -a ,,.41 6V:fw..:41 ,..idif?4,.It_ my '.'•,a. ffi Y - 7&---_,\,., \Al//7;�m� HE STATE 1 K,,,, '-1'.:W0f---:,:.141._::::::: 1 -- — — 33 Nes Sever', ,L i r ;G .�... / ( (s v f,4_1, ()1, 4,} 1; \ fp y I.11 PnCnOrC5 e, Alask.0 :";50' 3`,_,I2 SCANNED JUL 2 9 2Di4 Diana Guzman ��� Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1Y-10 Sundry Number: 314-285 Dear Ms. Guzman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / i° .;t2,(„_7 (,__ Cathy P Foerster // Chair DATED this /(�" day of May, 2014. Encl. STATE OF ALASKA RECEIVED AL .A OIL AND GAS CONSERVATION COMMI, iN Y 6 2 2014 • APPLICATION FOR SUNDRY APPROVALS MAY OrS s /<//5t-- 20 AAC 25.280 •1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell j . Change A,'• .0. .Q Suspend r Rug Perforations r Perforate r Pull Tubing r • Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. . Exploratory r Development r 183-051 , 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-20934-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No ' • Ail.\.l.,1Y-10 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25646 Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10115 6574 9478' 6156' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80' 80' SURFACE 2698 9.625 2727' 2199' PRODUCTION 7265 7 7294' 4837' LINER 2656 5 9608' 6242' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8872-9004,9213-9218,9234-9262,9282-9315 5774-5856,5986-5989,5999-6017,6030-6051 3.5x2.875x2.375 J-55 9146 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER 3.5"X 7"DB PERMANENT PACKER MD=6652 TVD=4413 PACKER-ECLIPSE PACKER MD=8868 TVD=5771 PACKER-BAKER 2 3/8'X 5 DB PACKER MD=9118 TVD=5926 SAFETY VLV-OTIS SERIES 10 SAFETY VALVE MD=1797 TVD=1628 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/2/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: VVINJ F' GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Diana Guzman @ 263-6318 Email: Diana.Guzman@conocophillips.com Printed Name Di. a Guzman Title: Sr.Wells Engineer #� I, ZOl1} Signature u`.6. Z. Phone:265-6318 Date/ 1�1 a-1 / Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness \LA-21?5 Plug Integrity P BOP Test Mechanical Integrity Test i'V 'ocation Clearance r RBDMS'1Y MAY 1 6 2(14 7e CSGO �, E or -- Other: �J Yr Atli--- 14- it-g�&'- Si-CLU. I;r-e • )E l'04;, - ,� �,,r,,,- C. rt C.--C-0�^C C --rto� c-.-:(A A 14 f n 2I. L Spacing Exception Required? Yes 0 No Subsequent Form Required: / 1) I (;`-( I/ ir, APPROVED BY Approved by: ��G COMMISSIONER THE COMMISSION Date: S��—//) S ,511 ApproveOpRatiGiiNN AL onths from the date a a of approval. Form 10-4I/(Revised 10/2012) /).151 Ij Submit Form and Attachments in Duplicate ConocoPh i l l i ps RECEIVED Alaska MAY 0 2 2014 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC April 30,2014 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover the Kuparuk Well 1Y- 10(PTD# 183-051). Well 1Y-10 was originally drilled and completed as a pre-producing injector in 1983 and started injection in 1986. From 1992 to 2002 well 1Y-10 was a MI WAG injector. A Leak Dectection Log showed that the C-sand selective was leaking in 1998.A tubing patch was installed in 2001, and injection into the A-sand only resumed. Well 1Y-10 failed a mechanical integrity test for the outer annulus(MIT—OA)in 2005. However, in 2007 after performing an Injection Profile/Leak Detect 2 leaks in the upper selective were identified and a patch failure was determined. Since then well 1Y-10 has been injecting into the C-sand un-controlled. Follow up diagnostics concerning the failed MIT- OA during pre-sealant preparation identified a surface casing leak at 228'. Well 1Y-10 was issued a water injection only waiver in 2009 and became part of the subsidence monitoring program. A Gyro performed in 2013 indicated that the tubing in 1Y-10 is showing signs of subsidence. Before being shut-in in 2013, well 1Y-10 was injecting 5000 bwpd. The purpose of this workover is to place the production casing back in tension to combat the effects of future subsidence as well as regain control of the injection into the A and C sands. This will be accomplished by stretching the production casing and replacing the tubing including the upper selective. Well 1Y-10 will remain online under the Water Injection Only waiver following the conditions established in the 2009 by the AOGCC. This Sundry is intended to request approval to workover well 1Y-10 with the proposed completion before subsidence makes this well un-securable in the future. If you have any questions or require any further information,please contact me at 907-265-6318. Sincerely, Diana Guzman Wells Engineer CPAI Drilling and Wells ' `- KUP 1Y-10 Conoc Phh1IIIps 1► Well Attributes Max Angle&MD TD hK Wellbore APUUWI Field Name Well Status Incl(°) MD(MEI) Act Btm(ftKB) . Alaska, c,,.,,,w,,,il,P,`.. 500292093400 KUPARUK RIVER UNIT INJ 58.20 4,000.00 10,115.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well Conrg:-1Y-10.626/2012 325'17 PM SSSV:TRDP Last WO: 10/1/1987 35.01 4/15/1983 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag: 9,247.0 7/16/1999 Rev Reason:WELL REVIEW osborl 6/26/2012 HANGER,26 Casing Strings ,, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String...String Top Thrd CONDUCTOR 16 _ 15.062 30.0 80.0 80.0 62.50 H-40 WELDED 'R Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 95/8 8.835 29.3 2,726.9 2,199.2 40.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd PRODUCTION 7 6276 29.4 7,294.1 4,836.6 26.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd LINER 5 4.408 6,951.8 9,607.5 6,241.6 15.00 K-55 FL4S Liner Details Top Depth CONDUCTOR, (TVD) Top Incl Nomi... 30430 Top(ftKB) (RKB) 1°) hem Description Comment ID(in) 6,951.8 4,612.6 47.50 HANGER BAKER LINER HANGER ASSEMBLY 4.408 II SAFETY VLV. 9,524.1 6,187.1 49.12 CATCHER BAKER CATCHER SUB ,4.408 1'797It Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 31/2 2.992 26.4 9,145.5 5,943.5 9.20 J-55 BTC-MOD 3.5)(2.875x2.375 Completion Details • Top Depth (ND) Top Incl Nomi.,, SURFACE, Top(ftKB) (ftKB) (°) Bern Description Comment ID(in) 262'727 26.4 26.4 0.25 HANGER FMC TUBING HANGER 3.500 1,797.2 1,628.1 44.96 SAFETY VLV OTIS SERIES 10 SAFETY VALVE 2.812 6,650.6 4,412.5 49.36 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.406 6,651.6 4,4132 49.35 PACKER BAKER 3.5"X 7"DB PERMANENT PACKER 3.250 GAS LIFT. 6,655.2 4,415.5 49.33 SBE XO BAKER 80-32 SEAL BORE EXTENSION w/XO TO 2 7/8"TUBING 2.437 6.611 6,734.7 4,467.6 48.80 NIPPLE AVA BPL PORTED NIPPLE 2.250 6,769.5 4,490.5 48.57 XO Reducing CROSSOVER 2.875 x 2.375 2.375 SEAL ASSY, 8,875.2 5,775.6 51.36 BLAST JTS STEEL BLAST JOINTS(8) 1.995 6.651 9,117.2 5,925.9 51.48 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 1.968 PACKER,6,652 ) 9,118.2 5,926.5 51.47 PACKER BAKER 2 3/8'x 5 DB PACKER 2.600 SBE XO,6.655 9,121.2 5,928.4 51.46 SBE BAKER 40-26 SEAL BORE EXTENSION 1.995 INJECTION,_ L. 9,132.1 5,935.2 51.43 NIPPLE CAMCO D NIPPLE NO GO 1.810 6,667 1 __ 9,143.9 5,942.5 51.39 SOS BAKER SHEAR OUT SUB,ELMD TTL @ 9136'during(PROF on 1.995 8/3/2007 NIPPLE,6,735 - --- ibther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ■ Top Depth (ND) Top Incl Ilr Top(ftKB) (ftKB) (°) _ Description Comment Run Date ID(in) 1 8,843.0. 5,755.4, 51.23 SLIPSTOP 2.0"SMS"A"TUBING STOP 12/20/2000 0.820 J IL 8,846.0 5,757.3 51.24 PACKOFF BAKER K-3 PACKOFF ASSEMBLY(31.25'long) 12/20/2000 0,800 8,868.0 5,771.1 51.33 PACKER ECLIPSE PACKER 12/20/2000 1.063 8,870.0 5,772.3 51.34 SPACER PIPE PATCH SPACER PIPE 12/20/2000 1.318 [Perforations&Slots Shot PRODUCTION, Top(TVD) Btm(TVD) Dens 29-7.294 Top(ftKB)Btm(SKS) (ftKB) (ftKB) Zone Date (sh••• Type Comment SLIPSTOP, 8,872.0 9,004.0 5,773.6 5,855.8 C-4,C-3,C-2, 4/15/1983 4.0 IPERF 33/8"SOS HyperJet 8,843 C-1,1Y-10 PACKOFF. 8.846 Y 9,213.0 9,218.0 5,986.1 5,989.2 A-5,1Y-10 4/15/1983 4.0 IPERF 33/8"SOS HyperJet PACKER.8,868 ° - 9,234.0 9,262.0 5,999.2 6,016.8 A-4,1Y-10 4/15/1983 4.0 IPERF 33/8"SOS HyperJet I9,282.0 9,315.0 6,029.5 6,050.7 A-3,1Y-10 4/27/1983 4.0 IPERF 3 3/8"SOS HyperJet SPACER PIPE, i1. Notes:. General&Safety. Q:I. 8,670 End Date Annotation IPERF, 11/11/1998 NOTE:Leak Detect Log found leak @ 8868'in 2.375 TBG 8.8729.004 1/4/2001 NOTE:Minimum ID is 0.80"@ 8868'. 1. 4/15/2006 NOTE:WAIVERED FOR OA x FORMATION COMMUNICATION 10/25/2010 NOTE:View Schematic w/Alaska Scheinatic9.0 SEAL A9,117SSY, PACKER,9,118 SBE,9,121 NIPPLE.9,132 IN 1 50S.9,144 ins 9.2133-9.218 Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Sue TRO Run 49, 9,23262 _ 4 Stn Top(ftKB) (RKB) (1 Make Model (in) Seri Type Type (Inl (pal) Run Date Com... 1 6,611.1 4,387.1 49.62 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0-10/3/1987 IPERF, 1 1 2 6,696.7 4,442.5 49.05 MERLA TMPD 1 INJ DMY BK 0.000 0.0102/1987 Closed 9,282-9,315 I I • A1.I LINER, 6,9529,607 , l TD,10,115 1 Y-10 Rig Workover • Pull & Replace Selective, • Stretch Production Casing (PTD #: 183-051) Current Status: This well is currently shut in and awaiting pre-RWO well work. Scope of Work: • Pull and replace upper selective • Stretch production casing General Well info: Well Type: Injector MASP: 1474 psi using 0.1 psi/ft gradient(Most recent SBHP= 1920 psi on 06/13/13)' Reservoir Pressure/TVD: 1920 psi/4461' TVD(8.29 ppg)on 06/13/13 . Wellhead type/pressure rating: FMC Gen II Retro/5M psi TH,3M Csg Hd. BOP configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams TIFL/MIT results: MIT-IA passed July 8,2013 MIT-OA failed June 5,2005, Earliest Estimated Start Date: July 16,2014 Production Engineer: Michael Sullivan Workover Engineer: Diana Guzman Work:265-6318 E-mail:Diana.Guzman@conocophillips.com Pre-Rig Work 1. RU Slickline: a. RIH w/dual Panex gauges to obtain SBHP.POOH b. Pull DV from GLM#1 and Injection andrel and leave open.Lock out SSSV. 2. PT tubing and casing packoffs,FT LDS's. 3. Set BPV. Proposed Procedure: 1. MIRU 2. Pull BPV. Circulate workover fluid. Obtain SITP& SICP, if still seeing pressure at surface, calculate new KWF,weight up,and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug,ND tree,NU BOPE&test to 3,000 psig. 4. Pull blanking plug&BPV. Screw in landing joint,BOLDS's,and pull tbg hgr to the rig floor. 5. POOH laying down 3 'h"tubing. { s a. If tubing will not pull free,RU E-line: Cut the tubing. ��' P 6. While pulling out of hole, MU storm packer. Set storm packer at—100'. NDBOP&Tbg head, stretch the casing, reland casing, cut excess casing, replace tbg head & IC packoffs, NU BOP & test. Pull storm packer. 7. RIH and fish tubing stub if needed. �50 �4 k Zr" ✓��� 8. MU packer mill. RIH and mill upper packer.POOH 9. RIH and fish tubing stub if needed. S+''""I_' 10. MU overshot/spear and RIH to packer. Engage packer and jar seal assembly free from lower packer. P / 11. PU tapered cleanout/scraper assembly and RIH to SBE. Circulate until returns are clean. POOH. ,, 12. MU upper selective on DP and RIH to SBE. �� 2 5 C��p5; - '-'-- cl„. //) 13. Engage SBE.Drop ball and rod. Pressure up to set the packer. PT IA. PU and shear out of PBR. 14. MU new 3 1/2"injector completion.RIH to PBR until fully located; 15. MU hanger. Load the IA w/corrosion inhibited completion fluid.Land the hanger,RILDS. 1 Y-10 Rig Workover • Pull & Replace Selective, • Stretch Production Casing (PTD #: 183-051) 16. PT the tubing to shear the SOV. 17. Pull the landing joint,install two-way check.PT two-way check through IA. 18. ND BOPE,NU tree. Pull BPV,install tree test plug. Test tree. Pull tree test plug. 19. Freeze protect well. 20. Set BPV. 21. RDMO. Post-Rig Work 1. Reset well house(s)and flowlines of adjacent wells. , 36 2. Pull BPV. /�. 3. RU Slickline: Pull SOV from GLM replace w/DV. Set up IL-injection. l 4. Handover to Ops to put back on injection. 1, �/ �1( 7 - (A- ConocoPhillips 1Y_10 Proposed Completion P&R Tubing with Upper Selective CONDUCTOR-16",62.58,H-40 a~ 2.875 DS Nipple @—500' WELDED @ 80'MD F SURFACE CSG 9.625",40#,J-55 BTC @ 2727'MD GLM Baker PBR @ 6651' CCE 1 Baker FHL Retrievable Packer @ 6652'MD f DS Nipple Injection Mandrel Injection Mandrel CMU Sliding Sleeve 4 TUBING—3.5"9.3#,L-80,8rd EUE PRODUCTION CSG—7",26#,J-55 @ 7294'MD ] l XO Reducing CROSSOVER—3.5" x 2.375"@ 6770' J )f BAKER LNR HANGER ASSEMBLY @ 6952' Steel Blast Joints(8)@ 8875' C-4,C-3,C-2,C-1 IPERF @ 5,774' - 5,856' t= I BAKER LOCATOR SEAL ASSEMBLY @ 9117 �} LC PACKER BAKER 2 3/8'x 5 DB PACKER @ 9,118' _ I ~ BAKER 40-26 SEAL BORE EXTENSION @ 9,121' SSL I +e CAMCO D NIPPLE NO GO @ 9,132' TUBING—2.375"6.4#,L-80,8rd EUE C ELMDTTL@9136' A-5 IPERF @ 9213'-9218' A-4 IPERF @ 9234'-9262' " A-3 IPERF @ 9282'-9315' ► LINER-5"15#,K-55 @ 9,607'MD Dale: ApriI30',2014 Drawn By: Diana Guzman • E.,v„c____ . ,. ,.,,,,, I lir , ,ost iii 4 17117 am ' 2M . gi.mt L., ' : . .. ..- Mii NMI I 410 II .111•11111 I:=1 ill ===::'. 111 IMO 1 1.1i' II i !! 3==:: ;211111.111 II% 41 .I.- all rf ii1L-11.111 , L' 11. MT; S it r firmy in ill IIr9 = . I C 11 4..--: 4j -- . 10111 al MOIL , Vir IIIII 1/: II ii. \di 15:: f ,� i --, ' - • R.M I 1111111 -- - 1111!11 I III 'llIs • I#' ; B a E 1 !1 Ill ' I /1\\ '11 I 1' ' /\ " \ SARAH PALIN,GOVERNOR LSSA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX 1907)276-7542 ADMINISTRATIVE APPROVAL AIO 2B.041 Ms. MJ Loveland Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510-0360 RE: KRU 1Y-10 (PTD 1830510)Request for Administrative Approval Kuparuk River Oil Pool Dear Ms. Loveland: In accordance with Rule 9 of Area Injection Order (MO) 02B.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby grants ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. Well diagnostics confirm the well has a surface casing leak at a depth of 228 feet. Rigless intervention efforts have been attempted to remediate the leak without success. CPAI intends to continue to evaluate and attempt remediation efforts. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 1 Y-10 exhibits at least two competent barriers — tubing/packer and production casing — to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in KRU 1Y-10 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates,and pressure bleeds for all annuli; 3. CPAI shall limit the inner annulus pressure to 2000 psi and the outer annulus -/ pressure to 100 psi; AI0 213.041 March 11,2009 Page 2 of 2 4. CPAI shall perform a mechanical integrity test of the inner annulus every 2 years to the maximum anticipated injection pressure; 5. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condi AOGCC approval shall be required to restart injection;and ty.ksh. a tG 7. The MIT anniversary date is May 10,2008. r r.'-44 DONE at Anchorage,Alaska and dated March 11, 2009. �, r fr dri 11L,:an, Daniel T. Seamount,Jr. Cathy I. Foerster `= o an Chair Commissioner o .:'s ner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the Commission grants for good cause shown,a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails,OR 30 days if the Commission otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the Commission,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails,OR 30 days if the Commission otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(6),"[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg • 2 G 1 l it DATE: Tuesday, July 19, 2011 P.I. Supervisor 6i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lY -l0 FROM: John Crisp KUPARUK RIV UNIT IY -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1Y -10 API Well Number: 50- 029 - 20934 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110717142451 Permit Number: 183 -051 -0 Inspection Date: 7/16/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1Y -10 Type Inj. W' TVD 4413 ' IA 251 3005 - 2863 2840 - P.T.Dt 1830510 ITypeTest I S Test psi 3000 ' OA 3.6 29.1 27.8 28.4 Interval RE Q V AR P/F P - Tubing 1500 1500 1500 1500 Notes: MIT IA as per ATO 2B.041 rule 9. 3.3 bbls pumped for test. Tuesday, July 19, 2011 Page 1 of 1 • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 04, 2011 2:05 PM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj D JAN 2 0 2" Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 -- message 3 Here is the latest addition to the email trail. t 20. 2A -03 - AA 2B.050 issued 6/9/2010. 19. 1Y -10 - AA 2B.041 issued 03/11/2009. Well last injected 01/10. 18. 1Y-09 - AA 2B.051 issued 05/20/2010. 17. 1Y-08 - AA 2B.056 issued 10/22/2010. Well last injected 04/07. Are there plans to return the well to operation? 16. 1Y -05 - AA 2B.0015 originally issued 09/12/06, revised 10/21/08. 2 year RST required (condition 3). Original RST 09/01/08, next RST 07/13/10; report "automatically" submitted by Halliburton. Since the RST is a requirement of the AA, the report should be submitted by Problem Wells. 15. 1Y -04 - Last injected 07/09. 7/5/09 email stated intention to keep on injection for diagnostics and possibly apply for AA. Apparently diagnostic results were inadequate for AA. 14. 1 Q -11 - AA 2B.058 issued 11/02/2010. I need to review condition 3 of AA for revision. From: Maunder, Thomas E (DOA) t: Tuesday, January 04, 2011 10:53 AM To: Well Integrity Proj Cc: 'NSK •blem Well Supv' Subject: RE: •nocoPhillips Monthly Injector Report - Dec 2010 All, I am continuing to review - December Monthly Injector report. I am through a • al of 13 wells. I wanted to send this latest message due what I have found or not found on 1Q-02B. • I continue to work through the report, I plan to send interim mes .es as I get 7 - 10 new wells review Call or message with any questions. 13. 1Q -02B - Well name is 1Q -02B. Well last i . -cted ' 0. I do not show having received any specific notification /request in June, 2010 regarding this - I. There is an email in the file from 4 /20/10 reporting diagnostics accomplished to that time containin.. state -nt that you intend to return the well to injection and remove it from the waiver report in May. 12. 1L-05 - AA 2B.054 issued 10/2 010. Well last injected 9/10 11. 1L-03A - Well name is -03A. Permit to Drill # is 199 -037. MITIA fa! :. 09/25/2010. Well last injected 9/10. 10. 1G-01 - AA =.035 issued 7/30/2008. 9. 1F-16' Well name is 1F-16A. IA DD failed 4/12/2007, but MITs are listed to have passe. ince. Well last inject- 4/2007. AA 2B.018 was issued in October 2007, but no injection has occurred into the we . ooking at th- •ressure plot, it is shown that the IA pressure appears to have been bled off in October and Novem. -r. Was 1/4/2011 • . The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [ mailto :n1617 ©conocophillips.com] �� ` Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 -659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 • • ConocoPhillips Well 1Y-10 Injection Data } • Tbg Psi IA Psi • OA Psi I 4000 3500 3000 - .N 2500 • a a 2000 • ,,• • 1500 w.••••.y • w • • • • • • • ••••••••• • • 1000 , • 500 0 09/10 10/10 11/10 12/10 01/11 Date PTD: 1830510 AA: AIO 2B.041 issued 03/11/09 Surface Casing Leak 5/4/2008 07/03/09 - State Witnessed (Lou Grimaldi) MITIA passed Well last injected 01/10. AIO 2B.041 requires any pressure bleeds to be reported monthly. No pressure bleeds have occurred in the past month • 0 ConocoPhillips Well 1Y-10 Injection Data • Water Injection • Gas Injection 1 4000 3500 3000 ; ♦r .° 2500 • Cl) Q a 2000. ♦ ♦ 1500 • • • .err • • 1000 i 500 • 0 0 1000 2000 3000 4000 5000 6000 7000 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected Pressure (mscfpd) (psi) (psi) (bwpd) (psi) 31- Dec -10 5175 0 1115 177 8 30- Dec -10 5222 0 1515 163 6 29- Dec -10 5080 0 2524 157 -11 28- Dec -10 5108 0 2890 169 -9 27- Dec -10 4989 0 2995 173 -6 26- Dec -10 5058 0 2888 188 0 25- Dec -10 5037 0 2028 201 1 24- Dec -10 4856 0 1591 181 -1 23- Dec -10 4652 0 1212 210 2 22- Dec -10 3496 0 1646 254 9 21- Dec -10 3460 0 1217 186 2 20- Dec -10 3441 0 1198 165 0 19- Dec -10 3405 0 1195 173 1 18- Dec -10 3359 0 1183 171 1 17- Dec -10 3407 0 1192 180 20 16- Dec -10 3452 0 1197 180 20 15- Dec -10 3393 0 1177 180 20 14- Dec -10 3382 0 1253 150 20 13- Dec -10 3452 0 1197 150 20 12- Dec -10 4177 0 1493 150 20 11- Dec -10 5276 0 2027 150 20 10- Dec -10 5256 0 1717 150 20 9- Dec -10 5259 0 1715 150 20 8- Dec -10 5288 0 1727 150 20 7- Dec -10 5244 0 1721 150 20 6- Dec -10 5253 0 1716 200 20 5- Dec -10 5308 0 1739 200 20 • • 4- Dec -10 5214 0 1723 200 20 3- Dec -10 5251 0 1730 200 20 2- Dec -10 5445 0 1779 200 20 1- Dec -10 5635 0 1823 200 20 30- Nov -10 5623 0 1820 200 20 29- Nov -10 5678 0 1824 200 20 28- Nov -10 5693 0 1831 200 20 27- Nov -10 5693 0 1828 250 20 26- Nov -10 5720 0 1826 250 20 25- Nov -10 5735 0 1833 250 20 24- Nov -10 5739 0 1836 250 20 23- Nov -10 5739 0 1825 250 20 22- Nov -10 5737 0 1827 250 20 21- Nov -10 5741 0 1854 250 20 20- Nov -10 5650 0 1791 250 20 19- Nov -10 5645 0 1777 350 20 18- Nov -10 5732 0 1817 350 20 17- Nov -10 5695 0 1808 350 20 16- Nov -10 5736 0 1902 350 20 15- Nov -10 5741 0 1907 350 20 14- Nov -10 5741 0 1915 350 20 13- Nov -10 5739 0 1899 350 20 12- Nov -10 5741 0 1903 350 20 11- Nov -10 5741 0 1888 350 20 10- Nov -10 5741 0 1900 350 20 9- Nov -10 5740 0 1853 350 20 8- Nov -10 4639 0 1501 350 20 7- Nov -10 3178 0 1018 6- Nov -10 2481 0 874 5- Nov -10 2364 0 840 4- Nov -10 2394 0 855 3- Nov -10 2361 0 841 300 2- Nov -10 2218 0 793 300 1- Nov -10 2252 0 792 300 10 31- Oct -10 2267 0 794 350 10 30- Oct -10 2647 0 904 400 50 29- Oct -10 5290 0 1656 275 20 28- Oct -10 2926 0 1218 275 20 27- Oct -10 5079 0 1671 275 20 26- Oct -10 4990 0 1641 25- Oct -10 5050 0 1656 275 20 24- Oct -10 5501 0 1779 275 20 23- Oct -10 5406 0 1742 275 20 22- Oct -10 4770 0 1561 275 20 21- Oct -10 5265 0 1702 20- Oct -10 5096 0 1657 200 20 19- Oct -10 5004 0 1629 200 20 18- Oct -10 4946 0 1611 200 20 17- Oct -10 5020 0 1630 200 20 16- Oct -10 4971 0 1609 200 20 15- Oct -10 5045 0 1633 150 20 14- Oct -10 5067 0 1641 150 20 • . 13- Oct -10 4927 0 1609 150 20 12- Oct -10 4397 0 1475 150 20 11- Oct -10 4439 0 1494 250 20 10- Oct -10 4466 0 1517 250 20 9- Oct -10 4640 0 1582 250 20 8- Oct -10 4611 0 1583 250 20 7- Oct -10 4654 0 1580 250 20 6- Oct -10 4620 0 1564 250 20 5- Oct -10 4556 0 1542 100 20 4- Oct -10 4542 0 1530 100 20 3- Oct -10 4633 0 1565 100 20 2- Oct -10 4528 0 1539 100 20 . MEMORANDUM To: Jim Regg '7 P.L Supervisor '~~C~9 7~3~ ~o~ ( FROM: Lou Grimaldi Petroleum Inspector CJ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 31, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Y-10 KUPARiJK RN iJNIT 1 Y-] 0 Src: Inspector NON-CONFIDENTIAL Reviewed B~ P1. Suprv ~~~ Comm Well Name: KUPARUK RIV iJNIT 1Y-10 API Well Number: 50-029-20934-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG090703154910 Permit Number: 183-051-0 / Inspection Date: ~~3/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. W@]j ~Y'~~ Type Inj. N T`~ 4413 ~ jA 920 3000 / 2870 2860 P.T.D Issos~o TypeTest SPT Test psi 3000 ~ pA o 0 0 0 Interval ~Q~~ P/F P Tubing ~oo too ioo ioo NOtes: 2_1 bbl's pumped, tested for compliance w/AIO 2B.041(?). Good test results , ,~~~ Y~ . ~~'~ ~r~S'S Lc~. ~~ S ' " `..~.,/`, `.'~-il~~l..`y~."~.~~ /V~~(''JL~~L1 ~~5.'~~'" . f ~ - it r"lii~~ .,~ `v.e ~~a ~ t p : c.. ~,. .. . L. ~m= ....m.; _ , . .. - Friday, July 31, 2009 Page 1 of 1 To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~ ~,,.,~ , ~ . . 130 West International Airport Road ~~~*~~~"~~o,.r ~~t~l: ~ ~' ~~~ Suite C Anchorage, AK 99518 Fay (907) 245-8952 1) Caliper Report 04-May-09 1 Y-02 1 Report/ EDE 50-029-20941-00 2) Caliper Report 04May-09 1 Y-10 v~ c 1~s3 - os°~ l~5 ~x~ r ~3 -~ r ~ ~~ ~; Signed Print Name: 1 Report / EDE 50-029-2093400 1 AY ~ ~ 2009 Dat~l~ ~missior~ anchorage PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchorageCc~mernorvlog.corn WEeSITE : ww~w.rr~errwevlog.corrs C:\Documents and Setiings\Ovmer\Desktap\Tiansmit_ConocA.docx • Memory Multi-Finger Caliper Lvg Results summary Company: __ __ Canocol'hiliips Alaska, Inc. Well: 1Y-10 Log Date: May 4, 2009 Field: Kuparuk Log No.: 7326 State: Alaska Run No.: 1 API No.: 50-029-2093400 Pipet Desc.: 3.5" 9.2 Ib. J-55 BTC AB-MOD Top Log 1ntv11.: Surtace Pipet Use: Tubing Bot. Log Intuit.: 6,665 Ft (MD) Pipet Desc.: 2.875" 6.5 Ib. J-55 EUE 8RD Top Log Intvl2.: 6,665 Ft. (MD) Pipet Use: Tubing Bot. Log Intvl2.: 6,735 ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage lnspection COMMENTS This caliper data is tied into the top of lrtl'ection Mandrel 2 C~ 6,697' (Driller's Uepth~. This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing and 2.875" tubing logged are in good condition, with no significant wall penetrations or areas of cross-sectional wall loss recorded. The caliper recordings indicate a minimum I.p. of 1.82" in the AVA BPL Ported Nipple at 6,735'. No other significant I.D. restrictions are recorded throughout the tubing logged. The caliper recordings indicate slight buckling throughout the 3.5" tubing and moderate buckling from surface to 1,780' (Jus# above the SSSV). The Body Region Analysis and Joint Tabulation Sheet for the 3.5" tubing and 2.875" tubing logged have been combined. 3.5" .& 2.875" TUBING -MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 15%) are recorded throughout the tubing logged. 3.5" S 2.875" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (>7%} are recorded throughout the tubing logged. 3.5" & 2.875" TUBING -MAXIMUM RECORDED ID RESTRICTIONS AVA BPL Ported Nipple Minimum LD. = 1.82" Jt. 213.1 C~3 6,735 Ft. (MD) No other significant I.D. restrictions are recorded throughout the tubing logged. ~$~ ~-: , ~ ;~~ Fiefd Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.Q. Box 1369, Stafford, TX 77497 Phone: (Z81) or {888) 565-9085 Fax: {281) 565-1369 E-mail: PDSCa?memorylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: {907) 659-2314 vz G l~s3 -~S"/ l~-99~ • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (9.8' - 6665.4') Well: 1 Y-10 Pipe 2 2.875 in (6665.4' - 6733.2') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: May 4, 2009 ^ A pprox. T ool De viation ^ Approx. B orehol e Profil e 14 781 1560 2361 D 3142 ~ i+ 6L s 3920 v O 4702 5483 6262 GLM 1 IJM 2 213.1 6733 0 50 1 00 Da mage P rofile (% wall) /Tool Deviatio n (degr ees) Bottom of Survey = 213.1 1 25 :.. ~, ~a - 50 ~~ 75 ~ 100 ..Q C Z _0 125 150 175 200 • PDS Report Overview m S Body Region Analysis Well: 1Y-10 Survey Date: May 4, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 2.875 ins 6.5 ppf )-55 EUE SRD 2.441 ins 2.875 ins 6.0 ins 6.0 ins 3.5 ins 9.2 ppf I-55 BTC AB-MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~~ metal loss body 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1°/~ 10%, 20% 40% 85% 8S% Number of 'oints anal sed total = 220 pene. 5 158 57 0 0 0 loss 131 89 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Nurnber of ~oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 n INJ~ 2 Bottom of Survey ~ 213.1 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1Y-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 4, 2009 Joint No. Jt. Depth (Ft.) I'e~n. Upset flns.) Pen. Body (Ins.) Ne'n. °~~> ~t~~t,~l I ~ ~,~ `;~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 10 (1 0.01 5 I .93 PUP 1 14 tt 0.01 2 I .88 Sli htbucklin . 1.1 46 t~ 0.01 ? _' 2.9 PUN 1.2 54 U 0.01 =1 _' 2.89 P P Lt. De sits. 2 62 a 0.01 3 ? .91 Sli htbucklin . 3 93 U 0.02 ~_'~ _' 2.89 Lt De osits. 4 124 O 0.01 2.88 5 156 t) 0.02 ti '~~ 2.88 Moderate bucklin Lt. De sits. 6 187 U 0.03 1 1 _' 2.88 Moderate bucklin Lt. De sits. 7 219 tt 0.04 15 ~ 2.91 Moder t bucklin Lt Ue sits. 8 250 ~~ 0.04 15 t~ 2.88 oderate bucklin L . De osits. 9 282 U 0.02 ti _' 2.92 Lt. De osits. 10 314 U 0.02 8 U 2.89 Sli htbucklin . 11 344 t) 0.01 Z _' 2.84 Lt. De osits. 12 376 n 0.01 > _' 2.92 13 408 U 0.02 ~) -1 2.76 Moderate bucklin Lt. De its. 14 440 t) 0.04 15 ~ 2.89 Moderate bucklin . 15 471 U 0.01 i 2.88 Lt. De sits. 16 5 3 t) 0.01 ~ I 2.91 1 533 t) 0.01 5 2.90 Sli htbucklin . 1 564 t ~ 0.01 ~ I 2.88 Lt. De osi ts. 19 596 U 0.01 Z I 2.90 20 627 t) 0.0 _' U 2.90 Moderate ucklin . 21 658 0 0.01 4 ? 2.89 Moderate bucklin . 90 0 0. 9 2.92 t o f 23 721 (1 0.01 4 ~' 2.90 24 753 U 0.02 ~) tt 2.86 Lt. D osits. 25 781 U 0.03 10 ~~ 2.86 Moderate bucklin Lt. De sits. 6 812 U 0.01 ~' I 2.87 Moderate bucklin . 27 843 tt 0.02 ~~ ~ 2.90 Moderate bucklin Lt. De sits. 8 875 a 0.01 2 U 2.91 29 907 U 0.01 2 I 2.91 Sli htbucklin . 30 935 U 0.01 4 tt .92 31 966 t) 0.03 I tl I 2.81 Lt. De osits. 3 998 0 0.01 4 u 2.89 Lt. D osits. 3 1028 U 0.02 ~) ~ 2.90 Moderate bucklin . 34 10 9 U 0.01 -1 1 2.88 od ra a bucklin . 35 1091 t? 0.03 1 3 ? 2.89 Moderate bucklin Lt. De sits. 36 1122 t~ .01 _' I 2.92 37 1153 a 0.01 ~' I 2.91 38 184 tt 0.02 ~) I 2. 39 1216 l~ 0.01 _' 1 2.91 Sli htbucklin . 40 1247 t l 0.02 E, t 2.91 41 1277 t7 0.01 4 ' 2.92 42 1309 ~ ~ 0.02 ~) I 2.90 43 1340 ~ ~ 0.00 1 ~, ~ 2.90 Lt. De osits. 44 1373 U 0.02 9 2.91 45 1404 t~ 0.02 t3 2.92 Lt. De osits. 46 1435 t~ 0.0 '? ~ .90 Moderate bucklin Lt. De its. 47 1465 a 0.02 " 2.90 ~{ Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.2 ppf }55 BTC AB-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 Y-10 Kuparuk ConocoPhillips Alaska, Inc. USA May 4, 2009 Joint No. Jt. Depth (Ft.) Pen. Ul~x~f (Irn.l Pen. Body (Ins.) Pen. °ib ~tef.il I cn~ ",~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 48 1497 it 0.0 15 ~ 2.91 49 1 9 u 0.03 11 2.90 50 60 t~ 0.02 8 93 li ht uckli 51 1591 U 0.01 ~ I .91 5 162 l ~ 0. 1 ~ 1 .90 53 1 54 U 0.03 13 I 2.87 Lt. De os'ts. 54 1685 U 0.02 t3 ~ 2. 8 LL e osits. 5 1717 l~ 0.04 1.5 ? 2.88 Sli ht bucklin . L D osits. 56 17 8 U 0. 3 13 I .90 Lt. De osits. 56.1 1779 t) 0.01 E~ Z 2.9 PUP 56. 1785 O 0 U U 2.81 O i Series 10 SSSV 6.3 1793 U 0.01 .; 1 .9 PUP 57 1800 U 0.03 13 3 2.88 t. De osi 5 1831 a 0.03 l 1 2 81 Sli t bucklin . L De si 18 2 U 0.03 1 ~ .88 a osits. 60 1894 U 0.03 1 3 ~ 2.89 Lt De osi 61 1926 ~ 0.03 1 1 .88 Lt De osits. 62 1956 U 0 03 13 t ~ .89 Sli h ucklin . 63 1987 t~ 0.02 9 1 2.89 64 019 t) 0.03 13 1 .88 t De osi 65 2050 t i 0.02 9 Z 2.91 66 0 1 n 0.04 14 U 2.86 L . De ~ts. 67 2112 (1 0.04 I5 U 2.89 68 2143 t~ 0.03 1 ~ 2 2.90 Sli ht bucklin . 175 ~ 0.03 lt) its 70 2207 t? 0.03 1(1 I 2.91 71 2238 U 0.04 I ~3 I .87 72 2269 tl 0.03 1 1 I 2.89 Lt. De osits. 3 2301 (~ 0.02 t3 .91 Sli t buc in 74 2330 t ~ 0.03 I t ~ ~ 2.88 75 2361 U 0.03 I 1 .84 t. De sits. 76 2393 l) 0.03 13 I 2.86 Lt De osits. 77 24 1 U 0.03 I1 2.89 78 2453 U 0.02 ~) t ~ 2.90 Sli ht bucklin . 79 482 t 1 .02 ~) 2.9 80 2514 t) 0.04 14 2.86 Lt. De osits. 81 546 t ~ 0. 3 12 1 .87 Lt. si 82 2577 U 0.03 1Z a 2.87 Lt. De osits. 83 2609 t) .02 9 Z 2.91 84 2641 U 0.03 1 1 I 2.87 Sli ht bucklin . 85 2672 !) 0.02 ~) I .9 Lt. a osits. 86 2703 n 0.03 l U 1 2.89 8 734 U 0.03 11 2.91 88 2765 U 0.02 ~~ I 2.91 Sli ht buckli 89 2797 U 0.0 1 U I 9 90 28 8 t ~ 0.03 1 tl _' 2.90 9 2860 (~ 0.04 14 I 2.80 Lt. De osi 9 2892 t~ 0.02 ~~ 1 2.87 Lt. De osits. 93 2923 0.03 1 ', 2. 8 t t. De osits. 94 2954 0.03 2.89 Sli ~ht bucklin . Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 Y-10 Kuparuk ConocoPhillips Alaska, Inc. USA May 4, 2009 Joint No. Jt. Depth (Ft.) Pen. UhsPt (Ins.) Pen. Body (Ins.) Pen. % ~1c~t,rl loss `;4, Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 95 2 5 t) 0.03 1 _; I 2.84 Lt. De osits. 96 3017 11 0.03 13 t 1 2.88 Lt. De osits. 97 3048 U 0.02 9 t 2.89 98 3079 U 0.03 10 I 2.90 99 3111 t) 0.02 9 I 2.89 Sli ht bucklin . 100 3142 t) 0.03 10 a 2.90 1 1 173 U 0.02 8 ~ 2.88 102 32 4 U 0.01 2 I 2.90 103 3235 t? 0.03 12 1 2.88 Lt De osits. 104 3267 U 0.02 9 2.93 Sli ht bucklin . 105 3 98 t) 0.01 ~ ! 2.91 106 3329 U 0.01 ? I 2.93 107 3360 t1 0.03 1 U ~ 2.90 108 3392 t) 0.01 ~' I 2.92 109 342 t_) 0.01 2 I 2.91 Lt. De osits. 110 3452 t 1 0.01 4 I 2.92 Sli ht bucklin . 111 3482 t ~ 0.01 2 I 2.91 1 2 3512 U 0.01 2 _' 2.90 Lt. Ue osits. 113 3544 t) 0.01 4 2.93 114 3575 t1 0.01 4 I 2.93 115 3607 t) 0.01 4 _' 2.92 116 3638 U 0.01 2 _' 2.92 Sli ht buckli 117 3670 U 0.01 2 I .91 118 3701 t) 0.03 1 t) 1 2.90 119 3 73 U 0.01 2 I .91 120 3763 U 0.0 5 1 2.93 121 3795 U 0.01 G I 2.91 122 3826 U 0.01 4 2.91 Sli ht bucklin . 123 3858 t) 0.03 12 2.92 124 3889 U 0.01 2 I 2.92 125 39 0 U 0.01 Z I 2.92 126 3952 U 0.01 4 (1 2.90 12 3984 t) 0.01 4 u 2.9 128 4015 t) 0.01 Z ? 2.92 129 4046 l) 0.02 ~~ _' 2.92 Sli ht bucklin . 130 4077 t) 0.01 2 I 2.91 131 4108 U 0.01 4 I 2.91 132 4139 U 0.02 f3 2.92 133 4171 U 0.01 2 ti 2.91 134 4202 t) 0.01 ~ I 2.92 135 4234 U 0.0 9 I 2.91 136 4265 U 0.01 ? 1 2.88 Sli ht bucklin . 137 4297 l) 0.03 I Z 1 2.88 138 4328 t) 0.01 ? 2.91 139 4360 a 0.01 ~' I 2.90 140 4390 a 0.02 ~> 2.91 141 4422 U 0.01 2 I 2.88 Lt. De osits. 142 4453 t 1 0.03 1 ? I 2.90 Lt. De osits. 143 4484 t ~ 0.03 11 I 2.87 144 4515 ~ ? 0.01 2 U 2.88 _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.2 ppf )-55 BTC AB•MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 Y-10 Kuparuk ConocoPhillips Alaska, Inc. USA May 4, 2009 Joint No. Jt. Depth (Ft.) I'en. UIxE~t !In<.) Pen. Body (Ins.) Nen. °/, ~tc~t~~l Ions "r4. Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 145 4545 c? 0.02 ~) ~' .88 li ht bucklin . 146 4577 a 0.0 ~> 1 2.91 147 4608 (I .03 1 l) 1 2.88 t. De osi ts. 148 4640 l) .03 12 I 2.88 Lt De o its. 149 4671 (1 0.03 12 I 2.8 Lt. De osi ts. 50 4702 tl 0.03 12 I 2.85 Lt. De osits. 151 47 3 U 0.04 15 ? .84 Lt De osits. 15 4765 t1 0.03 1.1 ~' 2. 0 t. De osiis. 153 4797 (1 0.03 1Z .' 2.86 t. a osits. 154 4827 l1 0.03 1 1 1 2.87 Sli ht buckl'n . De osits. 155 4859 U 0.03 12 I 2.85 Lt. De osits. 156 48 0 U 0.01 2 I .89 157 4922 ~) 0.03 11 1 2.9 158 4954 ~I 0.0 13 i .88 Lt. a os ts. 159 4984 U 0.0 11 ~' 2.91 60 501 O 0.0 ~) 2.91 li ht uc in . 161 5047 t ~ 0.02 ' I ~ 2.86 162 5079 U 0.03 I u ~ t 2.88 163 5110 O 0.01 4 t ~ .90 164 5141 a 0. 9 1 2.90 165 5173 I I 0.02 9 Z 2.94 Sli ht b cklin 166 5204 U 0.00 1 l) 2.90 167 5235 ~1 0.03 12 a 2.87 168 5267 l) 0.02 £3 a 2.93 169 5 98 O 0.02 `~ 2. 9 t De osi 170 5328 ~I 0.01 t> 2.92 171 360 I I 0.01 4 1 2.91 Lt. D osits. 172 5392 t) 0.01 2 U 2.92 Sli ht bucklin . 173 5420 (~ 0.02 9 i .92 174 5452 c t 0.01 5 I 2.90 175 5483 (1 0.01 5 _' 2.8 176 5513 tl 0.03 10 I1 2.88 Lt. De osits. 177 5542 (1 0.00 I ti .91 178 5572 l) 0.0 ~~ I 2.91 Sli ht bucklin . 179 5603 U 0.01 Z I .91 180 5635 U 0.01 i i 2.89 18 5667 U 0 01 ' 2 93 182 5699 U 0.03 1~1 t ~ 2.88 Lt De osits. 183 5730 (1 0.01 _' I 2.93 li h ucklin . 184 5762 (t 0.01 ~ I 2.91 185 5793 t1 0.00 I ~~ 2.91 186 5825 l) 0.00 I tl 2.93 187 5856 U 0.01 4 I 2.93 188 5888 (1 0.03 12 I 2.94 189 5919 U 0.01 2 I .89 Lt. o 'ts. 190 5951 U 0.01 ? I 2.91 191 5982 l? 0.01 2 I .90 Sli ht cklin . 192 6013 I ~ 0.01 2 I 2.91 1 3 6045 0.02 B 1 2 8 194 6073 0.02 ~3 _' 2.91 Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 Y-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 4, 2009 Joint No. Jt. Depth (Ft.) F'cn. l JI rsc t (Ins.) Pen. Body (Ins.) Nen. °ib V1c~tal I ~~ss ~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 195 6105 t ~ 0.01 _' I 2.91 196 6136 U 0.02 8 _' 2.91 Lt. De osits. 197 6167 U 0.01 S ~' 2.92 198 6199 t ~ 0.01 ? 2.93 Sli ht Buck in . 199 6230 ti 0.01 ~ I 2.88 Lt. De osits. 200 62 2 ~~ 0.01 ~ 2.88 201 6293 ~) 0.03 1 1 -i 2.90 Lt. De osits. 202 6324 t ~ 0.01 ,' I 2.90 . De osi ts. 203 6356 U 0.01 -1 1 .92 Lt De os 204 6388 t~ 0.02 ~~ ? 2. 0 205 6419 t~ 0.02 ti _' .91 Sli htbucklin . 206 6451 U 0. 3 t l -1 2.92 207 6482 t ~ 0.01 t~ 2.89 208 6514 t ~ 0.01 ? I 2.91 209 6545 U 0.01 4 t~ .91 L . De osits. 210 6576 ~ 0.01 ~1 I 2.91 Sli ht ucklin . 210.1 6606 t) 0.01 2 t) 2.97 PUP 210.2 6609 t i 0 U u N A GLM 1 Latch ~ 3:00 210.3 6616 tr 0.02 ti a 2.96 PUP 211 6617 a 0.02 ~~ ! 2.92 Sli htbucklin . 211.1 6649 i ~ 0 U u 2.41 Baker SBR 211.2 6652 t ~ 0 t ~ t t 3.25 Baker 7" x 3.5" 'DB' Perm Packer 212 6665 t) 0.01 ~ i 2.37 To of 2.875" Tubin 212.1 6697 t: 0 tt t~ N A In'ection Mandrel 2 Latch ~ 1:30 21 6704 t t 0.0 11 I 38 213.1 6733 U 0 U u 1.82 AVA BPL Ported Ni le _ Penetration Body Metal Loss Body Page 5 ~ PDS Report Cross Sections ~~, bNell: 1Y-10 Survey Date: May 4, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA tio. of Fingers: 24 Tubin 2.875 ins 6.5 f -55 EUE 8RD _ Analyst: C. Waldrop Cross Section for Joint 213.1 at depth 6734.653 ft Tool speed = 43 Nominal ID = 2.441 Upset OD = 2.875 Remaining wall area = i00 !n upset region Tool deviation = 105 ° Einger 15 Projection =-0.201 ins AVA BPL Ported Nipple Minimum I.D. = 1.82 ins HIGH SIDE= UP r- 1 L_J Cross Sections page 1 °;"~ PHILLIPS Alas~a Inc. ~u ~Y-~o \/ A Subsidia of PHILLIPS PETROLEUM COMPAM' ry • • „y , r l ` H j) I 71 1) 11 I 0 SARAN PALIN, GOVERNOR 1 r� 1 5 H 1 I � \ 11 AEASIIA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AIO 2B.041 Ms. MJ Loveland Problem Wells Supervisor ConocoPhillips Alaska, Inc. f JAN i b 'l.l)1I , P.O. Box 100360 Anchorage, AK 99510 -0360 RE: KRU 1Y -10 (PTD 1830510) Request for Administrative Approval Kuparuk River Oil Pool Dear Ms. Loveland: In accordance with Rule 9 of Area Injection Order (MO) 02B.000, the Alaska Oil and Gas s C ns i Commission (AOGCC or Commission) hereby grants ConocoPhillips o ervat on Co { ) y g p Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. Well diagnostics confirm the well has a surface casing leak at a depth of 228 feet. Rigless intervention efforts have been attempted to remediate the leak without success. CPAI intends to continue to evaluate and attempt remediation efforts. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 1Y-10 exhibits at least two competent barriers — tubing/packer and production casing — to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in KRU 1Y -10 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall limit the inner annulus pressure to 2000 psi and the outer annulus pressure to 100 psi; • • AlO 28.041 March 11, 2009 Page 2 of 2 4. CPA1 shall perform a mechanical integrity test of the inner annulus every 2 years to the maximum anticipated injection pressure; 5. CPA1 shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condi ... AOGCC approval shall be required to restart injection; and ra,N ` ...: �,t � 7. The MIT anniversary date is May 10, 2008. r _ c. DONE at Anchorage, Alaska and dated March 11, 2009. ' • 9 • /' //// Ai Daniel T. Seamount, Jr. Cathy ' . Foerster o • an Chair Commissioner . '.:'.ner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration m whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[title questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. i • • -iv ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 °< 1 4 f vos (.7008 March 8, 2009 4/),., o,.. -- 4 . 0 Mr. Jim Regg Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Regg: ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2B, Rule 9, to apply for Administrative Approval allowing well 1Y -10 (PTD 1830510) to be online in water only injection service with a known surface casing leak below the conductor. ConocoPhillips intends to pursue options to repair the casing leak at the deeper depth. If a viable option is available, the appropriate paperwork will be submitted at that time. If you need additional information, please contact myself or Martin Walters at 659 -7224, or MJ Loveland / Perry Klein at 659 -7043. Sincerely, /�f �� �'2 ,�,e e,,,/4,e,„„:5 Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Attachments ConocoPhillips Alaska, Inc. Kuparuk Well 1Y-10 (PTD 1830510) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue water only injection with known annular communication for Kuparuk injection well 1Y -10. Well History and Status Kuparuk River Unit well 1Y -10 (PTD 1830510) was drilled and completed in April 1983 as a development well, and was converted to a service well in October 1985. Follow up diagnostics concerning a failed MITOA during pre - sealant preparation identified a surface casing leak at 228', which is below the bottom of the conductor. The surface casing leak was reported to the AOGCC on 5/4/2008. Additional diagnostics performed on 05/10/2008, confirmed production casing and tubing integrity with a passing MITIA to 3000 psi as well as wellhead seal integrity based on passing tubing and inner casing pack off tests. Barrier and Hazard Evaluation Tubing: The 3.5" 9.2 # J -55 tubing has integrity to the packer at 6652' MD based on a passing MITIA performed on 05/10/2008. Production casing: The 7" 26# K -55 production casing with an internal yield pressure rating of 4980 psi has integrity to the packer at 6652' MD based on the MITIA described above. The well also passed a witnessed 4 year MITIA on 07/17/2006. Surface casing: The well is completed with 9 -5/8" 40# J -55 surface casing with an internal yield pressure rating of 3950 psi. The surface casing is set at 2726' MD (2200' TVD). Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or production casing it will be noted during the daily monitoring process. Any deviations from approved MAOP require investigation and corrective action, up to and including a shut -in of the well. T /I/O plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. NSK Problem Well Supervisor 3/8/2009 • . Approved Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed); 2. Inner annulus pressure not to exceed 2000 psi (40% internal yield) 3. Outer annulus pressure will be maintained as low as reasonably possible not to exceed 100 psi (2.5% internal yield) 4. Perform a passing MITIA every 2 -years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum); 5. Submit reports of daily injection volumes and tubing & IA pressures on a monthly basis; 6. Shut -in the well should MIT's or injection rates and pressures indicate further problems; 7. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification. NSK Problem Well Supervisor 3/8/2009 2 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; tom.maunder @alaska.gov; bob. Fleckenstein@ alaska. gov; doa .aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 1Y-10 DATE: 05/10/08 OPERATOR REP: Bates /Colee /Somaduroff - AES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 1Y -10 Type Inj. W TVD 4,413' Tubing 900 900 900 900 Interval 0 P.T.D. 1830510 Type test P _ Test psi 1500 Casing 200 3,000 2,975 2,970 P/F P Notes: Diagnostic MITIA for AA OA 250 250 250 250 Well Type Inj. TVD Tubing Interval P.T.D. _ Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 1Y -10 05- 10- 08.xls • • 0 PHILLIPS Alaska Inc. KRU 1Y -10 A Subsidiary of PHILLIPS PETROLEUM COMPANY 1Y -lo AP 500 Well Type: INJ Angle (dl TS: 52 deg © 8871 Last Update: 7/10/2001 SSSV SSSV Type: TRDP Orig Completion: 4/15/1983 Angle a TD: 49 deg © 10115 (1197 -1798, Annular Fluid: Last W /O: 10/1/1987 Rev Reason: Install PKR by ImO 00:3.500) Reference Log: Ref Log Date: Last Tag: 9247 TD: 10115 ftKB Last Tag Date: 7/16/1999 Max Hole Angle: 58 deg (c7? 4000 Casing String - ALL STRINGS Description Size Top Bottom ND Wt Grade Thread Gas Lift CONDUCTOR 16.000 0 80 80 - 62.50 H-40 Iandrel /Gummy SURF CASING 9.625 0 2726 2200 40.00 J -55 Valve 1 PROD CASING 7.000 0 7294 4836 26,00 K -55 (6611 -6612, LINER 5.000 6951 9607 6241 15.00 K -55 00:5.313) Tubing String - TUBING Size Top Bottom ND Wt Grade Thread 3.500 0 6665 4422 9.20 J -55 Zone Status Ft SPF Date Type BTC AB -MOD SBR 2.875 6665 6770 4491 6.50 J -55 EUE 8RD (6651 -6652, 2.375 6770 9145 5943 4.60 N-80 EUE 8RD 00:3.500) Perforations Summary Interval ND Comment 4;1: 8872 - 9004 5774 - 5856 4,C- 3,C -2,C 132 4 4/15/1983 IPERF 3 3/8" SOS HyperJet 9 213 - 9218 5986 - 5989 A -5 5 4 4/15/1983 IPERF 3 3/8" SOS HyperJet 9234 - 9262 - A-4 28 4 4/15/1983 IPERF 3 3/8" SOS HyperJet 33 4 4/27/1983 IPERF 3 3/8" SOS HyperJet 9282 - 9315 6030 - 6051 A -3 Injection Gas Lift MandrelsNa lves 6017 landrel /Dummy St MD N M an Man V Mfr V Type V OD Latch Port TRO Date Vlv VaIve2 1111._ _.__ Mfr Type Run Cmnt (6697 -6698, 1 6611 4386 Camco KBUG DMY 1.0 BK 0.000 0 10/3/1987 00:4.150) Injection MandrelsNalves St MD ND Man Man V Mfr V Type V OD Latch Port TRO Date Vlv NIP - Mfr Type Run Cmnt (6735 -6736, Ill 2 6697 4443 Meda TMPD DMY 1.0 BK 0.000 0 10/2/1987 Closed 00:2.875) Other (plugs, equip., etc.) - JEWELRY Depth ND Type Description ID 1797 1628 SSSV Otis Series 10 2.812 6651 4413 SBR Baker 2.406 6652 4413 PKR Baker 3.5" x 7" 'DB' Perm Packer 3.250 PACKOFF ---, Vt. , 6735 4468 NIP AVA BPL Ported Nipple 2.250 (8846 -8847. 8843 5756 TBG STOP Baker'A' Tubing Stop; Set 12 -20 -2000. 0.000 OD:1.815) 8846 5758 PACKOFF Baker K -3 Packoff Assy (31.25' long); set 12 -20 -00 0.800 8859 5766 SEAL Stinger Seal Assembly 2" x 12.5'; set 12 -20 -00. 0.000 TUBING 8868 5771 SEAL STINGER SEAL ASSEMBLY 0.840 (6170 -9145, 8868 5771 PKR 2 3/8" ECLIPSE SERIES III PACKER SET 12/16/2000 1.063 OD:2.315, 9118 5926 PKR Baker 2 -3/8" x 5 "'DB' Packer 2.600 10:1.995) 9132 5935 NIP Camco D' Nipple NO GO 1.810 9144 5943 SOS Baker 1.995 Pert 9145 5943 TTL 1.995 — (8872 -9004) — General Notes — Date Note _, 11/11/1998 Leak Detect Log on 1/11/98 found leak fti) 8868' in 2.375 tubing 1/4/2001 Minimum ID is 0.80" (d/ 8868'. PKR - - (9118 -9119, OD:3.625) NIP (9132 -9133, 00:2.375) Ell SOS . , (9144 -9145, --2_, OD:2.315) TTL - (9145-9146, OD:2.375) Pert — (9213 -9218) Pert _ (9234 -9262) 1 I — Pert _ (9282 -9315) CHOKE FTP FTT IAP OAP TIlIO Plot - 1Y-10 f 2600 ~- 1 .1 .l. I: .'. 1 .1 .'. I J .'. 5 J .'. 5 J .'. 4 l i f .'. 5 J 4 l .'. 5 F: .1• 1 1 J 1: 4 J 5 .'. 4 J 4 J .'. L J 4 f .I.4 l 5 J I = 200 2000 16a� �* 1500 = ,, r -- �; CL - 1000 - 100 _ i l l \ 600 _ �I I i _ '�' t i r '` 5 Ir ti '. ) I _ 0 1 0 - -- - - .a' I I I I I • I 08- D e c -08 21- D e c -08 03- Jan -09 16-Jan-09 29- Jan -09 11- Feb -09 24- Feb -09 Date • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • 4~ ~ tiff February 7, 2009 ~~~~_ ~ ~. ~,p t(a(~i;~ f~~~9~~~ i~ . ~ncl r u' Oi~S1p~ r~r~p~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 f°}~~ A ..I (~ V.. ~J M Dear Mr. Maunder: Please find the enclosed 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 1Y-10 (PTD 183-051, Sundry 309-011). The report records the unsuccessful surface casing repair attempt with Brinker Platelets. Please call MJ Loveland or Perry Klein at 659-7043 if you have any questions. Sincerely, ,~ `' ,~,,~ MJ Loveland Well Integrity Project Supervisor • • ~ t`~'{ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ~- ~ ~~)~~ REPORT OF SUNDRY WELL OPERATI(~y~ ~;~ ~ C;a~ ~~IE~ d, { : -y. 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ OttI~HG111:€f'3~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ SC repair W/ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ platelets 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhillips Alaska, Inc. Development ^ Exploratory ^ 183-051 ` 3. Address: Stratigraphic ^ Service^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20934-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 96' * 1Y-10 , 8. Property Designation: 10. Field/Pool(s): ADL 25646 i4LK 2577 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: ~z.~o.oR Total Depth measured ~9fa8r /D/j~ feet true vertical ~~?`~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 2630' 9-5/8" 2726' 2200' PRODUCTION 7198' 7" 7294' 4836' LINER 2656' S" 9607' 6241' Perforation depth: Measured depth: 8872-9004, 9213-9218, 9234-9262, 9282-9315 true vertical depth: 5774-5864, 5986-5989, 5999-6017, 6030-6051 Tubing (size, grade, and measured depth) 2-3/8", 2.875", 3.5" N-ao, J-55, J-55 9145', s~~o', ssse' Packers &SSSV (type 8~ measured depth) pkr= BAKER 3.5" X 7" DB PKR; BAKER 2-3/8" X 5" DB PKR; 2-3/8" Eclipse pkr pkr= 6652' ; 9118' ; 8868' SSSV= SSSV OTIS Series 10 TRDP SSSV= 1797' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: See enclosed report Of dally OperatlOnS 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A shut in 50 shut in Subsequent to operation N/A N/A shut in 25 shut in 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 ° Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAGQ - GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-011 Contact Perry Klein/ MJ Loveland Printed Name MJ Loveland Title Well Integrity Project Supervisor ~ Phone 659- 7043 Date ~y~~. ~ , ~ Signature ~~~,~ ~ r ~ ~ ~ ~ Form 101-404 Revised 04/2004 ~' '~ " ~ ~ ~ i~~~~ ~" t._.. `~~~~~~' ~~ ~ ~~ ' ~ ~~~~ ~-f ~~ Submit O ' ' al Only 2/d/q • 1 Y-10 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/30/09 Brinker Platelet SC Repair Pro'ect-Unsuccessful, Initial T/I/O=SI/50/0. ~ Rigged up Little Red Services to the platelet skid and started pumping diesel down the OA and established a LLR @ 1 bpm @ 120 psi., 2 bpm @ 160 psi, 3 bpm @ 190 psi and @ 4 bpm @ 220 psi. Loaded batch #1 of 100, 8 mm over molded cube platelets and pumped at a rate of 2 bpm @ 160 psi. OA started pressuring up between 500-700 psi indicatingylatelets @ leak oint. Loaded batch # 2 same as batch # 1. with similar results, pressure climbLing up to 700 psi and dropping off. Assumption is that platelets are too small. Loaded batch # 3 100 10 mm heavy platelet cubes. This time pressure would climb to 1100 psi and then drop off. Loaded batch # 4 50 25 by 10mm discs which seemed to have no effect at all. loaded batch # 5 100 15 mm heavy sphere platelets. As soon as pumping started pressure climbed to 1700+ psi, backed off rate with pressure falling and continuing to fall indicating the plates. that had starting to seal were no longer sealing. Loaded batch # 6 50 25 by10 mm discs, pumped for 2 minutes and loaded batch # 8 100 8 mm over molded platelet cubes. Unable to recreate increase in ressure seen in batch #5. Rigged down LRS and platelet skid. Final T/I/0= si/25/60 i PLATELETS® Overview & Case Studies Product ®verviemv Platelets° are an innovative means of sealing leaks in fluid flow applications such as pipelines, umbilicals and other items of system infrastructure. Platelets° are free floating, discrete particles which are injected into a system which has a known or suspected defect. The Platelets° are transported downstream with the flow in the system and when they reach a leak fluid forces entrain them into it thus providing a seal. This unique and innovative concept is based on the method the human body uses to heal wounds and can be optimised for a wide variety of fluid flow applications. ` Since Platelets° are deployed remotely they are a cost effective alternative to other remedial techniques such as clamps and wraps since direct access to the leak site, and therefore vessel intervention, is not required. Platelets° can be deployed in response to an emergency loss of containment incident but are most effectively incorporated as part of an ongoing integrity management programme to remove unnecessary system downtime. Platelet° material is selected depending upon the conditions within the system, such as pressure, temperature, fluid type, predicted leak geometry etc. but generally polymeric and elastomeric materials have the required characteristics for Oil & Gas applications. In all instances Platelets° are entirely inert and are therefore a low risk solution as they will have no negative effect on system infrastructure or indeed the carrier fluid. Platelets° can be introduced into a pipeline in a number of ways such as via pig launchers or by pumping through teeing points on the line; in all deployments to-date it has been possible to utilise existing infrastructure for injection and no modifications to the system have been required. Platelets° -The Facts • Remote deployment - no requirement for vessel intervention or access to leak site. • No requirement to shut-down, deployed whilst system operational. • Adaptability for variety of leak scenarios: corrosion pitting, fitting failures, hairline cracks, 6 o'clock grooves. • Emergency response or effective component of ongoing integrity management programme. • Temperature <_ 90°C, Pressure <_ 3,000 psi • (leak/ fDPipeline =120. ~L'rL~~~~l~ ~~~~U ,r~~~ ~i~~°~~. ALASSA OIL A1~TD GRAS COI~SERQATIOI~T COMI~II5SIOI~T -__J SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. ~kn~~ ,j~N ~ ~~~ P.O. 13ox 1003h0 ~ ` Anchorage, Alaska 99510 r, ~- a ~ ~~~ Re: Kuparuk River Field, Kuparuk Oil Pool, 1Y-10 Well Sundry Number: 309-011 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of January, 2009 Encl. ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 8, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~~ ~,~ ~v ~ ~~ ~~~9 ~'~~~Y,U ~I! ~ C~,:, j., ' ~(1i1S. COf ~°llCt)p,~~~,~, '~~~S.S1017 Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1Y-10 (PTD 183-051) surface casing repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures ,~ ~5.~`~~ ~ STATE OF ALASKA \~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~A,N ~, ~ ZOU~J i;~, APPLICATION FOR SUNDRY APPROV~41~ ~ 20 AAC 25.2so Alaska -I Gas Ccn~. ~~~~1;3sii~- 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ 35: ~~ V1laivel~ ^ Other Q Alter casing ^ Repair well ^/ Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved r ram g pp p og ^ Pull Tubing ^ Perforate New Pool ^ SC repair w1 ` Re-enter Suspended Well ^ Platelets 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 183-051 ` 3. Address: Stratigraphic ^ Service Q . 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20934-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO ~ 1Y-10 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25646 ALK 2577 RKB 96' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Uepth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10115' 6574' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 80' 80' SURFACE 2630' 9-5/8" 2726' 2200' PRODUCTION 7198' 7" 7284' 4836' LINER 2656' 5" 9607' 6241' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2-3/8" N-80 9145' 2.875" J-55 6770' 8872-9004,9213-9218,9234-9262,9282-9315 5774-5864,5986-5989,5999-6017,6030-6051 3.5" J-55 6665' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 3,5" X 7" DB PKR; BAKER 23/8" X 5" DB PKR; 23/8" Eclipse pkr pkr= 6652' ; 9118' ; 8868' SSSV= SSSV OTIS Series 10 TRDP SSSV= 1797' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 22, Zoos Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Perry Klein/ MJ Loveland Printed Name MJ Lovelan Title: Well Integrity Project Supervisor Signature Phone 659- 7043 Date ~ ~ J~ ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ~S'~ ~r,EC~~ Other: ~5,5~. ~~ ~--" 1. t f ~,~,( Subsequent Form Required: ~~ ~~ ')A~ ~ ~ L~Q9 APPROVED BY Approved b COMMISSIONER THE COMMISSION Date: . ~ ~ ..,..... ~ T~., ...,..~.,.. ~.,..... -~ ~ € t ~ ~ f F RECEIVES /• ~3 , 9' s • ConocoPhillips Alaska, Inc. Kuparuk We111Y-10 (PTD 183-051) SUNDRY NOTICE 10-403 APPROVAL REQUEST January 8, 2009 This application for Sundry approval for Kuparuk well 1Y-10 is for the repair of a surface casing leak. Kuparuk River Unit well 1Y-10 (PTD 183-051) was drilled and completed in April 1983 as a development well and subsequently converted to an injector. In May 2008 a surface casing leak was reported to the AOGCC. Subsequent testing indicates the leak depth in the surface casing is approximately 228' down from the OA valve. Due to the depth of the leak ConocoPhillips is planning a repair attempt with Brinker Platelets. Platelets are free floating (neutral density) discrete particles which are injected into the system (in this case the OA) and transported with the fluid flow and entrained in the leak with fluid force thus providing a seal. The Platelet material is entirely inert, designed to function in oil and gas applications and within the operating conditions of the well. Each partial is individually sized to fit the predicted leak geometry. With approval, repair of the surface casing will require the following general steps: 1. Rig up Platelet manifold to OA 2. Establish liquid leak rate; 3. Deploy a finite number of Platelets; 4. Maintain specified pressure on OA for a specific amount of time (to be determined by Platelet Tech, however probably less than 1000 psi). 5. MITOA to 1800 psi; 6. Return well to normal operations, however maintaining some positive pressure on OA. 7. File 10-404 • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Wednesday, January 14, 2009 12:54 PM To: Maunder, Thomas E (DOA) Subject: RE: Platelet Jobs Tom, The start date is Jan 22, 10 wells will be completed (1 per day). I just wanted approval for the 4 injectors before we started. MJ From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, January 14, 2009 12:44 PM To: NSK Well Integrity Proj Subject: Platelet Jobs Hi MJ, I have completed the review for 1Y-10 and 2T -05. Have platelet jobs on 3N -11 and 3Q -04 been accomplished yet? Thanks in advance for the information. Tom Maunder, PE AOGCC cAd JAN 0 ZO1 1/4/2011 MIT KRU IY-10 OS-IO-08.x1s Regg, James B (DOA) • Page 1 of 1 ~~3- From: NSK Problem Well Supv [n1617@conocophillips.comJ Sent: Saturday, May 31, 2008 1:29 PM ~~ ~~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Subject: MIT KRU 1Y-10 05-10-08.x1s Attachments: MIT KRU 1Y-10 05-10-08.x1s «MIT KRU 1Y-10 05-10-08.x1s» Attached for your records is an MITIA that was performed on the 1Y-10 well on 05/10/08. An application for Administrative Approval will follow. Please contact meat your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~~~NI~E®JUN ~ 9 2008 6/2/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 1Y-10 05/ 10/08 Bates/Colee/Somaduroff - AES ,v ~ b-3 .~~~~ ~ ~~ ~~~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 1Y-10 .Type Inj. W TVD 4,413' .Tubing 900 900 900 900 Interval O P.T.D. 183051 Type test P Test psi 1500 - Casing 200 3,00 2,975 2,970 P/F P Notes: Diagnostic MITIA for AA OA 250 250 250 250 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring 1 =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 1Y-10 05-10-OS.xls KRU 1Y-10 (PTD#,Report of Surface Casing Leak Page 1 of 1 Regg, James B (DOA) .From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, May 04, 2008 5:05 PM ~ '1 I~~~~ ~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF1 Prod Engr; CPF1 DS Lead Techs Subject: KRU 1Y-10 (PTD-~6~ Report of Surface Casing Leak `~?~_ ~~~ Attachments: 1Y-10 Well Schematic.pdf; 1Y-10 TIO Plot.ppt «1Y-10 Well Schematic.pdf» «1Y-10 TIO Plot.ppt» ~~~~ M/a~ ~ J~ 1~0~ Tom/Jim Kuparuk WAG injector 1Y-10 (PTD#. was diagnosed with a surface casing leak at 228' on 05/01/08. The T/IA/OA prior to initiation of work was 1450/260/0 and 1450/340/300 afterwards. Our immediate plan is to continue water injection in order to perform diagnostics including an MITIA and apply for an Administrative Approval to continue water only injection i necessary. Attached is a 90 day TIO plot and a wellbore schematic. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 5/19/2008 • Q t90 __.. ~C3 r ~' T a d3 I~. I~ ""~. • aC3 ~3 ~- ~ ~ ~ ~ ~~ ~. ,~ 1 '~' f i. d'Si C+- Ci3 I~ L, 'k~.; ~. L 1 .;... f P ~~ '~. r'! .5.. ±i3 Q ~ ~ '~ ~3 RC3 '~ ~.j a''"'!" {V r r ~~~ ~ ~~ ~~~ ~ ( U: Q L C . ~ 0 V U ~ N - • ~ C `~ : ; 1: t i• - i ~ Y ~RU 1 Y-10 (J, SehtuDlbergel' NO. 4384 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 2 17 2007 rn crS~NED ~UG 3 1 20111 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL 1 R-27 11850425 FPIT ,q / -It);).. 08/18/07 1 31-08 11839638 LDL J"'7r{~ -rM\ 07/28/07 1 2M-19 11813070 INJECTION PROFILE 1 IT" IC\ I - r.:;t'::) 07/29/07 1 3G-26 11813071 LDL J~q-^-::¡.:.ç- 07/30/07 1 1 R-18 11837482 SBHP/DDL Ie:; 1 ..: ^ 1S'?- 07/31/07 1 1Y-01 11813072 INJECTION PROFILE U:r¿ - Mr3-ù"'\ó 07/31/07 1 2C-08 11813073 INJECTION PROFILE' 11.,.." /1r<' -r-A.< 08/01/07 1 3H-32 11837483 LDL ~'1N"1 _Ñ, I 08/01/07 1 1Y-10 11837485 INJECTION PROFILE ·U~ 1~"'2..~ 08/03/07 1 3G-08 11813075 PRODUCTION PROFILE' .J~^ - () ",fir 08/04/07 1 1A-06 11837486 INJECTION PROFILE i )..." ~I-I1l.- 08/04/07 1 2N-337B 11837489 PRODUCTION PROFILE ',QA/ _ - If A~ 08/06/07 1 2U-08 11813076 LDL WI7\:. ~--^~ ( 08/06/07 1 1G-12 11837490 PRODUCTION PROFILE 1"6'3. - ~d. 08/07/07 1 2N-343 11745232 MEM INJECTION PROFILE . ()T(' Iq~- ~~ 08/08/07 1 2N-327 11837491 SONIC SCANNER ~ -:t -nln~ 08/08/07 2N-327 11837491 SONIC SCANNER-FMI .....,........ -,...... 08/08/07 3K-01 11632749 PRODUCTION PROFILE . IfrfD ~ 1,)/ 08/12/07 1 2X-04 11846430 INJECTION PROFILE I I-T.f\ I';'~ -II*' 08/13/07 1 2Z-29 11850419 SBHP SURVEY 1'7r"7r ":")::JCI 08/13/07 1 2X-19 11850420 SBHP SURVEY 1 t1 Ô - 1/),<'- 08/13/07 1 1A-20 11850421 SBHP SURVEY I ~f) - JI_~ 08/14/07 1 1 F-13 11850422 SBHP SURVEY I) '1J '\ I~ ,,'2., -1L/lJ 08/14/07 1 1H-10 11846432 SBHP SURVEY jt::¡-:< -tY~ 08/14/07 1 1Q-10 11846431 SBHP SURVEY j';r¿ - Jt: t '$r 08/14/07 1 2U-05 11846433 INJECTION PROFILE I ~ ":I:.f'. /lfr..c:;- - tìI~ 08/15/07 1 2D-12 11846434 PRODUCTION PROFILE j ~I..I - rA'-I 08/16/07 1 2H-06 11846435 LDL j~.c:: -IIß, 08/17/07 1 Kuparuk Color CD 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. '()7l 08/22/07 . . KRU MIT's ') ) Subject: KRU MIT's From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Mon, 06 Jun 2005 07:44:44 -0800 To: Thomas Maunder <tom_maunder@admin.state.akus>, James Regg <jim_regg@admin.state.akus>, bob _ fleckenstein@admin.state.ak us Tom, Attached are diagnostic MITIA's on 1Y-10 (PTD 183-051) and 1A-13 (PTD 181-195). The MITIA on 1A-13 was completed post patch - we will also schedule a state witnessed MIT after the well is brought on line. The MITIA on 1Y-10 was completed for IAxOA diagnostics. Please let me know if you have any questions. «MIT KRU 1Y-10 06-05-05.xls» «MIT KRU 1A-13 06-05-05.xls» MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 SCAi\U\JED JUN 1 4 2005 Content-Description: MIT KRU lY-lO 06-05-05.xls KRU IY-IO 06-05-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT KRU lA-13 06-05-05.xls MIT KRU IA-13 06-05-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 6/6/2005 7:53 AM ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: Kuparuk 1 KRU 11Y DATE: 06/05/05 OPERATOR REP: Brakel Rogers - AES AOGCC REP: Packer Depth Well 1Y-10 Type Inj S TV.D. 4413 Tubing P.TD. 1830510 Type Test P T est psi 1500 Casing Notes: Diagnositc MITIA Well Type Inj TV.D. Tubing P.T.D. Type Test T est psi 1500 Casing Notes: Well Type Inj T.V.D. Tubing P.T.D. Type Test T est psi 1500 Casing Notes: Well Type Inj TV.D. Tubing P.TD. Type Test T est psi 1500 Casing Notes: Well Type Inj T.V.D. Tubing P.TD. Type Test T est psi 1500 Casing Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas I nj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT Report Form Revised: 05/19/02 f&~~O 51 Pretest Initial 15 Min. 30 Min. 2520 2520 2520 2520 Interval 0 3100 3050 3000 P/F P 45 Min Reading 252013000 Interval P/F Interval P/F Interval P/F Interval P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) MIT KRU 1Y-10 06-05-05.xls 6/6/2005 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor DATE: FROM: John Crisp, SUBJECT: Petroleum Inspector May 17-18, 2001 Safety Valve Tests Kuparuk River Unit 1Y Pad May 17 & 18 ,,,2001: I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. ! witnessed one failure, the LPP failed to trip above 50% of primary separator pressure. The pilot was re-tested & passed the re-test. The AOGCC test report is attached for reference. I conducted 25 well house inspections on 1Y Pad. The majority of the houses were in good shape wi no problems witnessed. Well houses # 30 & 22 were found w/the well house lids resting on the tree cap gauges. The VSM for the 'flow line on well # 29 looked as if it had shifted up & had the line in a slight bind. I asked Phillips Rep. Pete Nezaticky to inspect this line. Prudhoe Bay Field has had problems wi VSM's shifting up & I wanted to make sure KRU Rep's were aware of this problem. .S, U.MMARY..: I witnessed SVS testing in Kuparuk River Field. 16 wells, 32 components tested. 1 failure witnessed. 3.13% failure rate. 25 well house inspections conducted. Attachmen.ts: SVS KRU 1Y 5-17 & 18-01jc cc~; NON-CONFIDENTIAL SVS KRU 1Y 5-t7 & 18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Ernie Bamdt AOGCC Rep: John Crisp Submitted By: John Crisp Date: 5/17 & 18/01 Field/Unit/Pad: Kupan~ River Unit 1Y Pad Separator psi: LPS 85 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code CEde Code Passed GAS or CYCLE 1Y-01 1830500 1Y-02 1830590 1Y-03 1830610 3750 2000 1800 P P WAG ,, 1Y-04 1830660 1Y-05 1830870 1Y-06A 1971340 85 70 55 P P OIL 1Y-07 1830680 1y-08 1830620 ,, 1Y-09 1830520 1YqO:: 183/)510 3750 2000: 1750 e P WAG 1Y-11 1830410 1Y-12 1830260 1Y-13 1830150 1Y-14 1830230 __ , 1 Y- 15A 1981860 85 70 50 P P OIL 1Y-16 1830420 1Y'17 1930680 85 60 60 'P P OIL , 1 Y- 18 1931060 1Y-19 1931070 8~ 60 65 P P OIL 1Y-21 1931020 85 70 65 P' P OIL 1Y-22 1930700 85 60 55 P P OIL 1Y-23 1930710 85 70 28 3 P 5/18/01 OIL 1Y-24 1930720 85 70 78 P e OIL 1Y-25 1880890 1Y-26A 1881160 85 70 50 P P OIL 1Y-27 193i)880 85 70 64 p p OiL 1Y-28 1930890 1Y-29 1880910 85 70 60 P P ' ' OIL . 1Y-30 1880900 85! 70 70 P P OIL 1Y-31 1930900 1Y-32 188~)930 85 70 70 P P " OIL 1Y-34 1930910 85 70 65 P P OIL ,, Wells: 16 Components: 32 Failures: 1 Failure Rate: 3.13% F190 oar RJF~Sel~/~r~s: Page ~ el2 SVS K?.U !Y 5-!7& !8-0!jc Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE RJF 1/16/01 Page 2 of 2 SVS KRU 1Y 5-17 & 18~01jc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 96 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 568' FNL, 1192' FWL, Sec.1, T11 N, R9E, UM (asp's 530861, 5974755) 1Y-10i At top of productive interval 9. Permit number / approval number 1056' FSL, 1453' FWL, Sec.2, T11 N, R9E, UM (asp's 525860, 5971084) 183-051 At effective depth 10. APl number 50-029-20934 At total depth 11. Field / Pool 928' FSL, 506' FWL, Sec.2, T11 N, R9E, UM (asp's 524913, 5970953) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 10115 feet Plugs (measured) Tagged PBTD (7/16/99) @ 9247' MD. true vertical 6574 feet Effective depth: measured 9247 feet Junk (measured) true vertical 6007 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 300 Sx AS II 80' 80' SURF CASING 2630' 9-5/8" 1250 Sx AS III, 250 AS I 2726' 2200' PROD CASING 7198' 7" 725 Sx G & 250 Sx AS I 7294' 4837' LINER 2656' 5" 1065 Sx Class G 9607' 6241' Perforation depth: measured 8872 - 9004'; 921 3 - 9218'; 9234 - 9262'; 9282 - 9315' true vertical 5774 - 5856'; 5986 - 5989'; 5999 - 6017'; 6030 - 6051' f'Jasl;a 0ii & Gas Cons. Com;'.r',issic:', /',nchoraa8 Tubing (size, grade, and measured depth) 3-1/2", 9.2#, J-55 Tbg @ 6665' MD; 2-7/8",6.5#, J-55 Tbg @ 6770' MD; & 2-3/8", 4.6#, N-80 Tbg @ 9145' MD. Packers & SSSV (type & measured depth) Baker 3.5 x 7" DB Perm Packer @ 6652' MD; Baker 2-3/8 x 5" DB Packer @ 9118' MD. Otis Series 10 @ 1797' 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 - 5846 2235 Subsequent to operation - 3714 2445 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __ Gas __ Suspended __ Service ~.(WAG)__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by John P'eirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1Y-10i STRADDLE PACKOFF INSTALLATION DESCRIPTION OF WORK COMPLETED 12/16/00: RIH & set a 29.8' x 1.865" Max OD Eclipse Packer at 8868' MD, w/element set at 8870' MD. 12/20100: RIH w/Eclipse Anchor Seal & Baker Stinger Seal Receptacle Assembly (12.5' x 1.867" OD, .875" Min OD), & set at 8859' MD. POOH. RIH w/Baker K-3 Packoff Assembly (31.25' x 1.815" OD; 0.800" Min OD), & set at 8846' MD. Pressured up on tubing to 2600 psi to shear disk in Eclipse Packer at 8868' MD, then performed an injection test at I bpm / 2350 psi. RD. Placed the well back on produced water injection & obtained a valid injection rate. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_X (sandback/cmt plug) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 72 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1518' FNL, 1989' FEL, Sec. 9, T10N, R14E, UM (asp's 674488, 5938804) 14-24 At top of productive interval 9. Permit number / approval number 221' FNL, 2704' FEL, Sec.9, T1 ON, R14E, UM (asp's 673740, 5940088) 183-091 At effective depth 10. APl number 50-029-20970 At total depth 11. Field / Pool 5249' FNL, 2716' FEL, Sec. 4, T1 ON, R14E, UM (asp's 673722, 5940334) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9586 feet Plugs (measured) PBTD Tagged @ 9240' MD on 9/20/2000. true vertical 9203 feet Effective depth: measured 9240 feet Junk (measured) true vertical 8898 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 400 Sx PF II 80' 80' Surface 2460' 13-3/8" 2000 sx Fondu & 400 Sx PFC 2532' 2532' Production 8902' 9-5/8" 500 sx Class G & 244 Sx PFC 8974' 8664' Liner 924' 7" 3o0 Sx C~ass G 9584' 9201' Perforation depth: measured 9161'- 9197'; 9202'- 9212'; 9215'- 9235'. ORI~I~t~L true vertical 8829' - 8860'; 8865' - 8874'; 8876' - 8894'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8614' MD; 4-1/2", 12.6#, N-80 PCT @ 8706' MD. : ~ ' '-' Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" BAKER FHL PACKER @ 8624' MD. x.' 5-1/2" CAMCO BAL-O SSSV NIPPLE W/DMY SSSV @ 2142' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 42 2168 1379 277 Subsequent to operation 338 662 542 225 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ___X Oil X Gas__ Suspended __ Service 17. I hereby certify that the f~regoing is true and correct to the best of my knowledge. Signed.~~~,,.~,~.___,.__,x~--- 'ritle: DSI4 Surveillance Engineer Date Brandon France ( ~ Prepared by Paul Rauf EE4.b'-Z99 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE~~ 14-24 DESCRIPTION OF WORK COMPLETED SAND PLUG ! CEMENT CAP FOR WSO & PERFORATING Date Event Summary 8/27/2000: 9/04/2000: 9/05/2000: 9/11/2000: 9/12/2000: 9/14/2000: 9/19/2000: 9/20/2000: RIH &tagged PBTD @ 9340' SLM. Dummied GLV's. A Sandback/Cement Cap for Water Shut off in the 7" liner was performed as follows: MIRU CTU. PT'd equipment to 4000 psi. Loaded & killed well w/1% KCL Water. RIH w/CT & tagged PBTD @ 9367' (::;TM. Pumped a gelled sand slurry containing 1600 lbs of 20/40 mesh River Sand to isolate a liner leak @ 9310'. Made a final TOS tag @ 9270'. POOH w/ CT. Pumped 3/4 bbls of 15.8 ppg Class G cement onto the sand plug to form a cap. POOH. FP'd well. Estimated TOC @ 9250'. RD. RIH & tagged TOO @ 9249' SLM. Installed GLV's. Performed inflow test - passed. MIRU ELU. PT'd equipmemt. RIH w perforating guns & reperf'd the following intervals: 9173'- 9183' (Zone 4) Reference Log: BHCS 6/26/1983. 9215' - 9235' (Zone 4) Used 2-7/8" carriers & all shots @ 4 SPF. Lodged perf gun in hole - unable to free. Disconnected & POOH leaving 24' fish in hole. FP'd well. Post perf injection rate 6 bpm @ 2000 psi. RD. RIH & latched fish @ 9222'. POOH w/perf gun. ASF. RIH & tagged PBTD @ 9240'. Placed well on production & obtained a well test. Page 1 Memory Multi-Finger Caliper Log Results INAL Company: Phillips Alaska, Inc. Well: 1Y-10 Log Date: October 16, 2000 Field: Kuparak (CPF-1) LOg No.: 4178 State: Alaska Run No.: 1 APl No.: 50-029-20934-00 Pipe Desc.: 2.375 EUE 8rd. N-80 Top Log Intvl: 8,422 Ft. (MD) Pipe Use: Tubing Bot. Log Intvl: 9,132 Ft. (MD) Inspection Type: Pre-Patch Evaluation COMMENTS: This survey was run to assess the condition of the tubing with respect to corrosive and mechanical damages with special emphasis on patch placement. This Icg was tied into SWS Injection Profile Dated July 16, 1999. The caliper recordings indicate that the tubing ranges from good to poor with respect to corrosive damage. A single hole was recorded at 8,865.6'. This hole is in the first full joint above what appears to be 8 Blast Joints. (8,864' - 9,033') No other significant damage was recorded through the interval logged. MAXIMUM RECORDED WALL PENETRATIONS: Hole (100%) Jt. 14' @ 8,865.6 ELMD MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall-loss (in excess of 9%) are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: The most noticeable ID restrictions are in the 8 blast joints between 8,864' - 9,033'. The ID in this interval is approximately 1.85" This is believed to be a result of increased wall thickness and not scale build-up. Jt. # 14 refers to the number of joints logged with the caliper and has nothing to do with any tubing tally or completion running order. RECEIV ED Field Engineer' R. Liddelow Analyst: R. Richey OCT 2 2000 Alas~ 0il & Gas Cons. c0mmissi0r Witness: Chuck Fi~n~l~r~c~'° ProActive Diagnostic Services, :[nc. / 310 K Street Suite 200, Anchorage, Alaska 99501 Phone: (907) 245-895:1. Fax: (907) 245-8952 E-mail: PDSanchorage@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Well: 1Y-10 Field: Kuparuk (CPF-1) Company: Phillips Alaska, Inc. Country: USA PDS Caliper Overview Body Region Analysis Survey Date: Oct. 16, 2000 Tool Type: MFC24 No. 00387 Tool Size: 1 11/16" No. of Fingers: 24 Analysed: Robert A. Richey Tubing: Size Weight Grade & Thread 2.375 ins 4.6 ppf L-80 EUE Nom. O D Nom. I D Nom. Upset 2.375 ins 1.995 ins 2.375 ins Penetration and Metal Loss (% wall) penetration body ~ metal loss body 20 10 0 11, ii_111 _ 0to 1to 10to 20 to 40 to above 1% 10% 20% 40% 85% 85% Number of joints analysed (total: 27) Pene 11 1 14 0 0 1 Loss 11 16 0 0 0 0 Damage Configuration ( body ) isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 1) 0 0 0 0 I Damage Profile (% wall) penetration body 10 15 metal loss body 50 100 J~l II II &. I! ii i1 i! ! ! Bottom of Survey = 16.3 Analysis Overview page 2 RECEIVED OCT 2,,~ ~000 AJaska Oil & Oas Cons. Commission Anchorage PDS CALIPER JOINT TABULATION SHEET Pipe: 2.375 ins 4.6 ppf L-80 EUE Wall thickness. Body: 0.190ins Upset -- 0.190ins Nominal ID: 1.995 ins Well: 1Y-10 Field: Kuparuk (CPF-1) Company: Phillips Alaska, Inc. Country: USA Date: Oct. 16, 2000 penetration body metal loss body Joint Penetration Metal ProjedJon Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inches inches 3 50 10 .1 0 0 0 0 0 0 0 1 0 .03 14 3 0 0 1.97 m. 2 0 .02 13 3 0 0 1.96 m 3 0 .03 15 4 0 .05 1.94 Lt. Deposits. mm 4 0 .03 14 3 0 .03 1.94 mm 5 0 .03 15 6 0 .04 1.94 Lt. Deposits. I~ m 6 0 .03 14 4 0 .04 1.93 Lt. Deposits. mm 7 0 .03 14 3 0 .04 1.94 Lt. Deposits. m, 8 0 .03 15 3 0 .04 1.93 Lt. Deposits. mm 9 0 .02 13 2 0 .03 1.96 m 10 0 .03 15 4 0 0 1.96 mm 11 0 .03 16 4 0 .03 1.95 mm 12 0 .03 15 4 .05 .05 1.94 Lt. Deposits. mm 13 0 .03 13 3 0 .05 1.92 Lt. Deposits. m 14 0 .21 100 9 0 .03 1.95 HOLE ! m 14.1 0 0 0 0 0 .04 1.92 PUP Reduced ID. Possible Blast Jt. 14.2 0 0 0 0 0 .04 1.93 PUP Reduced ID. Possible Blast it. 14.3 0 0 0 0 0 .04 1.93 PUP Reduced ID. Possible Blast it. 14.4 0 0 0 0 0 .04 1.93 PUP Reduced ID. Possible Blast Jt. 14.5 0 0 0 0 0 .04 1.93 PUP Reduced ID. Possible Blast Jt. 14.6 0 0 0[ 0 0 .05 1.92 PUP Reduced ID. Possible Blast )t. 14.7 0 0 (3 0 0 .05 1.92 PUP Reduced ID. Possible Blast Jt. 14.8 0 0 (] 0 0 .05 1.91 PUP Reduced ID. Possible Blast Jt. 14.9 0 .01 4 0 0 .06 1.91 PUP 3 Pup's Combined as 1 Assembly m 15 0 .03 14 3 0 .05 1.94 Lt. Deposits. mm 16 0 0 C 0 0 0 1.96 16.1 0 0 0 0 0 0 1.79 PACKER 16.2[ 0 .00 1 2 .11 .11 1.79 PUP 16.3 [ 0 0 0 0 0 0 0 XN Damage Classifications Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 75% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference General - damage depth range exceeds I * pipe ID and/or extends more than 20% of circumference Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference Damage reporting threshold = 30 thou inches deviation in body, 50 thou in upset. Modal line length = 0.500 feet. Pipe Tabulations page 1 ! I ! ! ! ! ) ! ! J ) } ! ) } } J ! J Well: 1Y-10 Field: Kuparuk (CPF-1) Company: Phillips Alaska, Inc. Country: USA Tubinl~: 2.375 ins 4.6 ppf L-80 EUE PDS Caliper Sections Survey Date: Oct. 16, 2000 Tool Type: MFC24 No. 00387 Tool Size: 1 11/16" No. of Fingers: 24 Analysed: Robert A. Richey Cross section for Joint 14 at depth Tool speed -- 40 Nominal ID = 1.995 Nominal OD -- 2.375 Remaining wall area = 95 % Tool deviation = 55 ° 8865.62 ft Finger 2 Penetration = 0.207 ins HOLE HIGH SIDE=UP RECEIVED o CT 2 :~ [!00(~ Nask~ Oil,& Gas Cons. Comml~lon Anchorage Cross-Sections page 1 PDS CALIPER JOINT TALLY SHEET Pipe: 2.375 ins 4.6 ppf L-80 EUE Wall thickness. Body: 0.190ins Upset = 0.190ins Nominal ID: 1.995 ins Well: 1Y-10 Field: Kuparuk (CPF-1) Company: Phillips Alaska, Inc. Country: USA Date: Oct. 16, 2000 Joint Depth Length Measured Type No. ID feet feet inches .1 8411.30 7.97 nominal Pup I 8419.27 32.44 nominal 2 8451.71 32.41 nominal 3 8484.12 32.30 nominal 4 8516.42 32.50 nominal 5 8548.92 32.58 nominal 6 8581.50 32.53 nominal 7 8614.03 32.41 nominal 8 8646.44 32.49 nominal 9 8678.93 32.49 nominal 10 8711.42 32.48 nominal 11 8743.90 32.40 nominal 12 8776.30 32.67 nominal 13 8808.97 32.29 nominal 14 8841.26 32.31 nominal 14.1 8873.57 19.94 nominal Pup 14.2 8893.51 19.79 nominal Pup 14.3 8913.30 19.85 nominal Pup 14.4 8933.15 19.97 nominal Pup 14.5 8953.12 19.75 nominal Pup 14.6 8972.88 19.90 nominal Pup 14.7 8992.77 19.95 nominal Pup 14.8 9012.72 19.87 nominal Pup 14.9 9032.59 18.28 nominal Pup 15 9050.87 32.43 nominal 16 9083.30 32.86 nominal 16.1 9116.16 7.88 nominal Packer 16.2 9124.04 7.63 nominal Pup 16.3 9131.66 unknown nominal D Nip Joint Depth Length Measured Type No. ID feet feet inches OCT 2 000 Oil,& 8as Cons. Commission Anchorage Joint Tally page 1 0ct-24-00 03:56pm From-MARATHON 0IL M. arathon OdCompany +glS~8484~g T-801 P. 02/05 ska Region uomesflc Production F-88g P.O. I~ox 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564-6489 October 24, 2000 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: KBU 23x-61 Dear Mr. Wondzell: Enclosed is the APPLICATION FOR SUNDRY APPROVALS for well KBU 23x-61. Please advise if additional information is required. I can be reached at 564-6317 or e- mailed at dmtitus@marathonoil.com. Sincerely, Denise Titus Production Engineer Enclosure 0¢t-~4-00 0~:~6pm From-~ARATHON 0IL +~15~$4~48~ T-801 P. 03/0S tol~o STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request; Abandon~ Suspend_._. Operation Shutdown ...-- Re-enter Suspended Well Alter Casing.~- Repair Well ~x Plugging ~ Time Extension ~ Stimulate Change Approved Program Pull Tubing Variance Perforate Olher 2, Name'o~ Operator '-'-- s. '~¥pe of We-iff 6, D~t~-m Elevation (l~F-0r KB) MARATHON OIL COMPANY Development._.~_x Pad 66' MS1. . J 3,--Ad'dreee - Exploratory ~ 7, Unit or Property F, O, I~ox 196165, Anchom,~e, AK g9519-6168 Stra~graphic~ _Kenai Beluga Unit .... ,~. LocmiDn of Well at Surf~ce Service 8, Well Numbb~ ' 291' N & 1208' E of SW Comer Seat 23x-6L At top of Productive Interval ' e, permlfN~nber ' 1468' N & 1491' E of SW Comer 84-109 , lO', APl Number h sand throu 0-13 - .0871 .... 24:~1' N & 1704' E of ~W ,,Comer ..... , , Ken~i":{3~~ Fleld/Belu.qa Pool 12. Pre:~ent"Well Condition Summ~y Total Deplh; measured 6960 feet Plugs (measured) ,') ,,'j ~' ,,- j ,% ~ true verticat 6447 feet '~ F'--' . ..... Effeclive Depth; mea~red 6B41 feet Junk (rneaeured) : . true vertical 6341 feet ~:" '.~ C~sing Length S~e Cemented Measured Depth True Vedical Depth Structural Conductor Surfeca 126' 20' Driven 126' 1~6' Intermediate 2532' 13-3/B" 1870 sx 2582' 2454' Production 6~5o' 9-~rs" 6950' 6447' Liner Perforation Depth: measured 8t 12'-6810' true vertical 4711'-6311' Tubing (size, grade, and measured depth) 3-112", ~),2 ppf, N-80, 5074'O ,JGJNAL Packers and $~V (type and measured depth) WD Packer @ 6007'/Dual @ 41 13'i Attachments ' D~sc~ipt~on $-~mr~a~ of Pmposal~ O~.,iled-Opere, tiona program ~ -BOP Sketch ~ " ~ 4. EMimated-Date for Comm6n~in9 Opera'd~n 1~'. ~'t~,tus of W~It' Classification ~s: 10/28/00 '16. If I:;~posel was ~/er'bally Approved OI!~ Gas.~_X Suspended ~ Name of Approver Date Approved Service , ,,, ,, 17. ! hereby c, erti[y that the loregoir~g is true and correuff to [he best of m~/knowledge, - ,, '-' ' ~ Fo-R-COI~MISSI-O'N-U$'E ONLY ' ' ' ,~. Plug Integrity BOP Test / Location Mechanical Integrity Test ~ ~ubsequent Fa .n'~. _Required lO-'-~ (~ .... ORIGINAL $IGN~-U ~ ~ Approved by,,Order of the Commission ~ Taylor Seamount/~) ,.~) ~- , Commi,e.ipner Rev, .~lsmit in Tripll-(~te * Oct-Z4-O0 03:$6pm From-MARATHON OIL T-;O1 P.04/OS F-6;g KBU 23x.61 Kenai Gas Field, Pad 14-6 Sand Wash Procedure Objective: Sand fill on lower peffs restricts well flow. As a result the wellbore is loaded with water. Run in with 1%" CT and wash sand. Jet well in with nitrogen. .- , Procedure: 1) MIRU Dowell 1 ~" CT_ 2) Pressure test to 2000 psi. 3) Rill w/wash nozzle. Expect sand at 5640'. Wash sand to 6850' taking returns to open top tank through chicksan and gas busten 4) Once returns are clean, POOH pumping nitrogen. 5) Turn well to system and produce per instruction of production engineer. I0124/00, DM7' · Oct-Z4-O0 03:$?pm From-MARATHON OIL /~.,. +gl~58484gg T-801 P.05/O~ F-$Sg I - - III ~ B-3 Sd. Beluga v CASING & ABANDONMENT DETAIL I. Slaver,on Kelly Bushing at 0.0' II. CAmeron Dual Tubinq Hanger at 25.4 I' Ill. 20', 94~, H-40 Driven to 126' IV. ~3-318", 61., K-(iS Buttress Casing ~l 2.$38° V. E.T.D. ~t 6,841' VI. 9-~/8", 47~,, N-60 Casing at 6,950° · TUBING DETAIL LONG STRING: 3-1/2", 3.2~, N'80 TUBING 1. Otis ~XA' Sleeve at 4.116.04' 2. Otis Moctet 'RDH° Dual Packer at 4,155.04' Otis 'XA* Sleeve al 4,t80.57' 4. Blast Joints From 4,199,Z1° to 4,29B.63' Otis 'XA" Sleeve st 4,971.90' 6. Otis Straight 8lot Locater Sub al 5,008.40' ?. Otis Molded 13esl Asseml~l¥ From 5,007.76' to 5,0 18.11' Otis MO~Iel 'We° Pro~. Pa~Rer al 5,007'. g. Otis 'X' Nlogle at 5,050.57' 10. Bottom of Otis Mule 5hoe et 5,074.27' SHORT STRING: 3-1/2", 9.2.~, IV-gO TUBING A. Otis 'XA* Sleeve at 4,085,40' B. Otis Maclel 'RDH" Duel Pa~:ker at 4,154.71' C. Bottom of Otis 'XN" Niep~e at 4,173.16' PERFORATION RECORD DA TE INTER VA L CONDITION 2123185 ~,78B'-6,810' 5,520'-6,54~0 z~- f~eluga Zn. Proau~tion 5.112°-~. 129' 4.214'-4,~75' B-3 Sd. Praductlon i _ i , WELL KBU 2:3X-6 WELL SCHEMATIC UNION OIL COMPANY hi= ~, ...... .'~ - ....... To: Re". Well Name I.o~ 'l"ype Run i)Mc Kuparuk River Unii iE-iA Kuparuk River Unit 1A-II Kupa~k River Unil 1 I.-10 Kuparuk River Unit 1L-14 Kupanwk River Unit IL-17 .Kupamk River U',fit IL-22 Kupamk River Unit IR 04 Kuparuk River Unit 1Y-10 Kuparuk Kuparuk Kuparuk Kuparuk Kt]paJuk Kupan,k Kuparuk Kuparuk Kuparuk Kupa[uk Kuparuk Kuparuk Rix~er Unit 1Y-12 River Unit 1¥-15 River unit 2~08 I~ver Unit 2C-02 Rive, Unit 2C~04 River Unit 2C 05 lfiver Unit 2C-06 I~vcr Unit 2V-13 I~v~r Unit Unit ti--0 River Unit 3G-20 Wa~er Flow [.og Injection Profile Injection Profile Injection Profile Injection Profile Injection P~ofile Injection Profile Injection Profile injection Injection Profile Injection Profile Injection .Profile Injection Profile Injection Profile Survey Injection Profile Survey Injection Profile Production l.og Production Log Injection Profile Injection Profile Survey Injection Profile 07.IAN1991 10-1-91 03 NOVEMBERI991 4 NOVEMBI£R 1991 4 NOVEMBFR 1991 11~06--1991 6/30/91 12-13-.--1991 1 I-i9 91 11-.17-1991 12--2-91 12-27--1991 26 DEC 1991 10-27--1991 11/25/91 11~16-1991 8-.IiJNE-1991 :3 l-J UL¥-- 1991 11 NOV 1991 10/119/91 11--29-1991 [-!::ceiYed by: ~ Dated: Copy sent to sender: Yes ~/ No ~ RECEIVED MAR 2 6 1992 Alaska 011 & Gas Cons. Commission Anchorage Re: Injector T x IA communication Subject: Re: Injector T x IA communication Date: Tue, 26 Sep 2000 17:11:33 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Jerry C Dethlefs <JDETHLEF@ppco.com> CC: Lou Grimaldi <lou_grimaldi@admin.state.ak. us> Jerry, Unfortunately if the wells didn't break would you have a job? I guess you would reporting all the information regarding the wells that didn't break. Your plan sounds good. Please keep us informed. Also, please give me a call in the morning and we can discuss scheduling the Alpine stuff you asked about. Tom Jerry C Dethlefs wrote: > Tom: This is getting to be routine, t4hich is not a good thing/. While preparing a > list of wells for upcoming injector MIT's at Kuparuk we found a well with high > IA pressure that may be communicating with the tubing. The well is 2F-04, is on > gas injection (3750 psi), and has an IA pressure of 2700 psi. After bleeding the > gas off the IA fluid came to the surface at 2200 psi. I don't think our > communication is severe or the IA would have been equalized with the tubing. > There are a couple possible sources of communication; packoffs, (1) gaslift > valve, or a thread leak I propose we get this on a list to: 1) swap back to > water; 2) set a tailplug and MIT the tubing; and 3) change out the gaslift valve > (existing is a dummy). > I don't think we can get a good MITIA with the well in the existing state. If > this sounds ok to you we will proceed with that plan. > Jerry Dethlefs > Phillips Problem Well Supervisor Tom Maunder <tom maunder~.admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 12:02 PM MEMORANDUM TO: Dan Seamount Commissioner THRU: Blair Wondzell P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: ChuckSchev~,~.~_ S, Petroleum Inspector NON- CONFIDENTIAL DATE: August 21,2000 SUBJECT: Blowout Preventer Test XTO "A" Cross Timbers Platform A A44-02 184-075 Middle Ground Shoal Operator Rep.: Larry Driskill Contractor Rep.: Brad Rasch Test Pressures RamS: 250~5000 MISC. INSPECTIONS: P/F P/F Location Gen.' P Sign: P Housekeeping: P Rig cond: P PTD On Location P Hazard: P Standing Order: P Op. phone: 776-2534 Op. E-Mail: Rig phone: Rig E-Mail: Annular: 250/2500 Choke: 250/5000 TEST DATA FLOOR VALVES: MUD SYSTEM: Visual Alarm Quantity P/F Trip Tank P P Upper Kelly 1 P Pit Level Indicators P P Lower Kelly 1 P Flow Indicator P P Ball Type 2 P Meth Gas Detector P P Inside BOP 1 P H2S Gas Detector P P BOP STACK: Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 13 5/8 P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams 1 2 7/8 P Quantity P/F System Pressure 3050 P Lower Pipe Rams No. Valves 13 P After Closure 1750 P Blind Rams 1 P Man. Chokes 1 P 200 psi Attained 25 SEC P Choke Ln. Valves 1 3 1/8 P Hyd. Chokes 1 P Full Pressure 2:30 P HCR Valves 1 3 1/8 P Blind Covers (All Stations): P Kill Line Valves 2 2 P N2 Bottles (avg): 4@ 2500 Check Valve N/A Test's Details I arrived on board thc platform and found the rig in the process of rigging up having just completed a leg to leg move. All BOP components functioned properly and held their pressure tests. The Inlet Drilling crews demonstrated good test procedures allowing the pressure tests to be completed in the minimum number of steps. The gas detector alarms functioned properly but the sensors appeared tocout of calibration. When 50% LEL test gas was applied the read out climbed to 100% LEL. The rig gas detectors are part of the platform system and thus are calibrated by a XTO instrument tech who was not on board at this time. With the sensors reading at a higher level than the test ~-_z._t' ~' gas applied I allowed operations to continue with the understanding that all sensors be recalibrate when the insmunent tech returns to the platform. Total Test Time: 4 Number of failures: 1 Attatchments: CC: Vugdvlht.xls 8/28/00 MEMORANDUM TO: THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Aug. 20, 2000 SUBJECT: Dan Seamount~/'/~"~/O Commissioner O Blair Wondzell ~~ P.I, Supervisor ~ ~o'; JeffJone~ J~---j , Petroleum Inspector NON- CONFIDENTIAL Blowout Preventer Test Nabors #54 Unocal G-18 DPM 183-1350 MacArthur River/Trading Bay Unit Operator Rep.: Terry Coleman Contractor Rep.: Rick Brumley Op. phone: 776-6630 Rig phone: 776-6634 Op. E-Mail: colemant@unocal,com Rig E-Maih Test Pressures Rams: 3K MISC. INSPECTIONS: P/F Location Gen.: Housekeeping: PTD On Location Standing Order: P Sign: P Rig cond: P Hazard: P BOP STACK: Annular: 3K Choke: 314, TEST DATA FLOOR VALVES: P/F Quantity P/F F Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P F H2S Gas Detector P P Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 13 5/8 P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams 1 3 1/2 P Quantity P/F System Pressure 3000 P Lower Pipe Rams 1 3 1/2 x 5 P No. Valves 13 P After Closure 1300 P Blind Rams 1 13 5/8 P Man. Chokes 1 P 200 psi Attained 49 sec. P Choke Ln. Valves 2 4 1/16 P Hyd. Chokes 2 P Full Pressure 3 min. P HCR Valves 1 4 1/16 P Blind Covers (All Stations): P Kill Line Valves 2 3 1/16 P N2 Bottles (avg): 4~ 2100 P Check Valve N/A Test's Details On August 19, 2000 I traveled to Unocal's Grayling platform in Cook Inlet, where Nabors Drilling personnel were preparing to test BOPE prior to a workover operation on well #G-18 DPM. Testing began August 20, 2000 at approximately 16:30 hrs. and concluded at 20:30 hrs. The rig equipment appeared clean and in good condition and the drilling crew performed the BOPE tests in a safe and competent manner, with one failure. There was no well sign displayed on the rig, and Rick Bramley (contractor rep.) indicated he will have one installed. The Kelly valves will be tested before their next use with documentation forwarded to the A.O.G.C.C's Anchorage office. I witnessed successful alarm tests on the rig floor and mud pit H2S and methane gas detection devices. Summary: I witnessed the initial BOPE test and a random gas alarm system test on Unocal's Grayling platform where Nabors Drilling crews are performing a re-completion of Unocal's well #G-18 DPM. Total Test Time: 4hrs. Number of failures: 1 cc: Attachments: none BOPE Nabors .xls 8/28/00 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 22, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION 1 Y- 10 Convert to WAG Inj. 1 Y- 16 /2~¢-~-,z. jv ¢_,j ~ Leak Detection 3M-1 3 al%r,- ~'-Q-14 Fracture If you have any questions, please call me at 263-4281. F ract u re Fracture Sincerely, C. W. Strickland Operations Engineer CC: J. D. Bolling M. C. Pearson K©E1.4-9 ATO-1196 ATO-1176 (w/o attachments) (w/o attachments) RECEIVED V 2 6 1991 Alaska Oil & 8as Cons, Cor~mlsslen 'Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate __ Plugging Perforate _ Pull tubing Alter casing Repair well 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 4. Location of well at surface 568' FNL, 1192' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1056' FSL, 1453' FWL, Sec. 2, T11N, R9E, UM At effective depth 928' FSL, 985' FWL, Sec. 2, T11N, R9E, UM At total depth 928' FSL, 506' FWL, Sec. 2, T11N, R9E, UM 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor 8 0' Surface 2 7 2 6' 10115' true vertical 6573' measured 9 4 7 8' true vertical 6156' Length Size 9 5/8" Intermediate Production 729 4' 7" Liner 2 6 5 6' 5" Perforation depth: measured 9282'-9315', true vertical 6028'-6049', Tubing (size, grade, and measured depth) feet Plugs (measured) feet feet Junk (measured) feet Cemented 300 Sx AS III 1250 Sx AS III & 250 Sx AS I 725 Sx Class G & 250 Sx AS I 900 Sx Class G 9234'-9262', 9213'-9218', 6. Datum elevation (DF or KB) 96' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-10 9. Permit number/approval number 83-51 feet 10. APl number 50-029-20934 11. Field/Pool Kuparuk River Oil Pool Measured depth True vertical depth 80' 80' 2726' 2199' 7294' 6951'-9607' 8872'-9004' 5997'-6015', 5984'-5987', 5773'-5792' 4835' 4612'-6239' 3 1/2 9.2# J55 0'-6655', 2 7/8 6.5# N80 6655'-6769', 2 3/8 4.7# N80 6769'-9145' Packers and SSSV (type and measured depth) 3 1/2" OTIS SSSV Series 10 @ 1797', 3 1/2 Baker "DB"@ 6652', 2 3/8 Baker "DB" @__9118' 13. Stimulation or cement squeeze summary RECEIV[U 14. Intervals treated (measured) N 0V 2 6 1991 Treatment description including volumes used and final pressure Convert well to miscible gas alternating water injector. No downhole work completed. Al, eh, Nil ,~,_ RP.S C0[IS._ ; t{~01.t.t~p~[1 Representative Daily Average Production or Injectio'n"~'~{~-'- ]~ctl0rag~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 3766 180 2344 Subsequent to operation 0 4693 0 0 3129 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil _ Gas Suspended Water Alternating Service Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Date 11/2'?" / Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ~DQS I NINQ WELL REPORT FOR lO/O ~1 DRILLSITE 1Y PAGE 1 W Z S E 0 T L N A L E T PRODUCTION WELL STATUS 7" 10" TP TT WC H2S CS~ CSQ PSI CHK DEQ % PPM PSI PSI LIFT STATUS SI CN GAS INJ AH TEMP METER RATE LI DEQ READING MSCF EB · .~=/I IMPACT C H M 0 R I D EPL S N E GBL.,ii, 3 B PR 4 B PR 5 B PR 6 A PR 14 B PR 16 A TS 25 B PR 26 B PR 29 B PR 30 B PR 32 B PR 180 176 121 60 278 176 154 70 209 176 141 70 177 176 131 98 207 100 111 44 305 176 120 36 203 176 121 50 191 176 142 65 277 176 141 70 219 176 138 70 224 176 134 70 60 1240 300 47 1460 240 60 1320 1280 60 1300 300 30 1100 900 40 740 0 45 1000 600 60 1240 900 60 120 220 62 1400 760 75 1200 900 92 0 1259 0 100 0 1130 0 100 0 2404 0 102 0 1114 0 86 0 1264 0 66 0 466 0 74 0 819 0 76 0 423 0 46 0 0 0 52 0 0 0 58 0 164 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 O 0000 0 0 0000 0 0 0000 0 0 0000 0 0 TOTALS' 9043 0 W Z S E 0 T L N A L E T 1 B MI 2 B PW 7 B PW 8 B SI 9 B PW 10 B MI 11 B PW 12 B PW 13 B MI 15 B PW TOTALS' INJECTION WELL STATUS INJECTION RATE ALLOW PSI ACT 7" 10" INO TT CSQ CS9 PSI DE9 CH½ PSI PSI 2500 3152' 111 100 0 0 2500 1382 162 12 120 0 2500 1478 157 12 20- 20 4000 0 0 0 50 0 2500 2~16 144 10 120 200 2500 3129 112 100 0 0 2500 2225 154 12 360 100 2500 140:~ 158 12 1100 0 4000 2~93 11~ 100 0 0 ~500 ~198 145 10 1~0 80 4. INO INJ METER RATE RATE READINQ BPD MMSCFD iIimI~ 0 0 5.370 0 3338 0 000 0 3792 0 000 0 0 0 001 0 1888 0 000 0 0 4 693 0 5010 0 000 0 1962 0 000 0 0 14 209 0 4227 0o000 0 + PWI' 20217 = 20217 24.273 S/I C H M 0 R I D S N E 0000 0 0000 0 0000 0 2400 51 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 2, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate is an Application for Sundry Approval on the following well. Well Action 1Y-10 Conversion AnticiDated Start Date October, 1991 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer RECEIVED OCT .. 4 1991 Alaska Oil & 6as Cons. Corn~jssjlll] w. H. Carter ATe 1120 KeEl .4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMIb_,ON APPLICATION FOR SUNDRY APPROVALS ORIGINAL 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program X Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulatem Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic 4. Location of well at surface 568' FNL, 1192' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1056' FSL, 1453' FWL, Sec. 2, T11N, R9E, UM At effective depth 982' FSL, 985' FWL, Sec. 2, T11N, R9E, UM At total depth 928' FSL, 506' FWL, Sec/2. T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 10115 feet 6573 feet 9478 feet 6156 feet Casing Length Size Structural Conductor 8 0' 9 5/8" Surface 2 7 2 6' Intermediate Production 7 2 9 4' 7" Liner Perforation depth: 9282'-9315', Plugs (measured) Junk (measured) Cemented 300 Sx AS II 1250 Sx AS III & 250 Sx AS I 6028'-6049', 2656' 5" measured 9234'-9262', 9213'-9218', true vertical 5997'-6015', 5984'-5987', 13. Convert water injector to miscible cjas alternating] water injector 14. Estimated date for commencing operation 10/6/91 6. Datum elevation (DF or KB) RKB 96' 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-10 feet 9. Permit number 83-51 10. APl number so-029-20934 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 80' 80' 2726' 2199' 725 Sx Class G & 7294' 4835' 250 Sx AS I 900SxClassG 6951 '-9607' 461 2'-6239' 8872'-9004' 5773'-5792' RECEIVED Tubing (size, grade, and measured depth) O CT.. 41991 3 1/2', 9.2' J-55 0'-6655'; 2 7/8', 6.Bl~ N-80, 6655'-6769'; 2 3/8', 4.7# N-80, 6769~'/'~9g/,~aS'0 Packers and SSSV (W~ and measured depth) il ~ Gas Co~s. ~0~iss~ 3 1/2" OTIS SSSV Series 10 ~ 1797', 3 1/2" Baker "DB" ~ 6652', 2 3/8" Baker "DB" ~ 9118' ~___ . - '. A~achments Description summary of proposal _ Detailed operation program _ ~~h _ Status of well classification as: Oil m Gas __ Suspended 16. If proposal was v/~rbally Name of approvelj('4~$'3 Si~ned f I.,/uv-'k ~., 15. Service Water ~jlternating gas in!ector Date apl~roved / j~) ..-~. - ~ I ~'~ "~ Date approved forego'ng is true and correct to the best of my knowledge. Title ~ ¢ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test m Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 09/12/90 JAppro.v.,al No._2 .. SUBMIT IN TRIPLICATE ~' STATE OF ALASKA ALASKA ~lL AND GAS CONSERVATION CO,v~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~,~ REV I SED OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE~] WATER IN.IFCTr)R .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-51 3. Address 8..APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 029-20934 4. Location of well at surface 9. Unit or Lease Name 568' FNL, 1192' FWL, Sec. 1, TllN, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1056' FSL, 1453' FWL, Sec. 2, TllN, RgE, UM 1Y-10 At Total Depth 11. Field and Pool 928' FSL, 506' FWL, Sec. 2, TllN, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Kuparuk Ri ver Oi 1 Pool RKB 96'I ADL 25646 ALK 2577 12' Date Spudded03/23/83 13. Date T.D. Reached04/03/83 14' Date C°mp'~ Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns04/15/83* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MEH-TVD) 19. D~,ectional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10115'MD, 6573'TVD 9478'MD, 6156'TVD YES ~ NO []~ 2158 feet MD 1350' (approx) 22. Type EleCtric or Other Logs Run D I L/SFL/SP/GR/FDC/CNL/Cal, Gyro/CBL 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 80' 24" 300 sx AS II 9-5/8" 40.0# J-55 Surf 2726' 12-1/4" 1250 sx AS Ill & 250 sx AS I 7" 26.0# J-55 Surf 7294' 8-1/2" 725 sx Class G & 250 sx AS I 5" 15.0# K-55 6951' 9607' 6-1/8" 900 sx Class G Liner lap squeezed w/165 sx Cla~s G 24. Perforations open to Productior! (MD+TvD of Top and B°ttom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf 3-1/2"/2-7/8"~ 9145' 6652' & 9118' 8872'-9004'MD 5773'-5792'TVD 2-3/8" 9213'-9218'MD 5984'-5987'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 9234'-9262'MD 5997'-6015'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9282'-9315'MD 6028'-6049'TVD See Well Service report attached to Well Cornpl~.inn report dated 11 /16/87; fur fracture 27. N/A PRODUCTION TEST Date First Production ' ' I Method of Operat'ion (Flowing, gas lift, etC.) I Date of Test Hour~ Tested IPRODUCTION FOR OI L-BBL GAS-MCF WATERIBBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~ I OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of 'lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEiVEI) · .;~ska 0il & Gas Cons. *Note: Workover performed 7/27/87 & 10/2/87. Fractured well 10/23/87. Anchorage Form 10-407 Rev. 7-1-80 WC4/74 :DAN I CONTINUED ON REVERSE SIDE Submit in duplicat~y 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERs MEAS. DEPTH 8866' 9004' 9201' 9406' TRUEVERT. DEPTH 5769' 5855' 5977' 6109' 30. FORMATION TESTS 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 Signed ~//~~ ,,~J./'//,,/.-~,.~ Title Associate Engineer 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION t, OMMISSION · 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. 83-51 , · . 3. Address 8. Apl Number P. 0. Box 100360, Anchorage, AK 99510-0:360 50- 029-20934 .... 4'. Location of wel'l at surface 9. Unit or Lease Name 568' FNL, 1192' FWL, Sec. 1, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1056' FSL, 1453' FWL, Sec. 2, TllN, R9E, UM 1Y-lO At Total Depth 11. Field and Pool 928' FSL, 506' FWL, Sec. 2, T11N, RgE, UM Kuparuk River Field , - 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 96' ADL 25646 ALK 2577 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 03/23/83 04/03/83 04/15/8:3' N/A feet MSL 1 ~7. T°talDepth(MD+TVD) 18. Plug Back Depth (I~lD+TVD) 19. DireCtional Survey I 20. Depth where SSSV set 121.Thickness of Permafrost 10~115'MD, 6573'WD 9478'MD, 6156'TVD YES ~ NO []. 2158'. feet MD _ 1350' (approx) 22~ Type Electric or Other 'Logs Run .... D 1L/SFL/SP/GR/FDC/CNL/Ca 1, Gyro/CBL 23. '" CASING, LINER AND cEMEN'~-ING RECORD · SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# U-40 Surf 80' 24" 300 sx AS II 9-5/8" 40.0# J'-55 Surf 2726' 12-1/4" 1250 sx AS Ill & 250 s~ AS I 7" '26.0# J-5~ ~urf 7294' 8-1/2" 725 sx Class G & 250 ix AS I 5" 15~0# " K-55 ' ' 6951' 9607" 6-1/8" 900 sx Class G Liner lap squeezed w/l.;5 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD , interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf 3-1/2"/2-7/8"/ 9145' 6652' & 9118' 8872 ' -9004 'MD 5773 ' -5792 'TVD 2-3/8" 9213'-9218'MD 5984'-5987'TVD 26. ACID, FRACTURE, cEMENT SQUEEZe, ETC. 9234'-9262'MD 5997'-6015'TVD DEPTH IN'TERVAL (MD)' AMOUNT &'KIND-(~F-M'ATERIAL USED · . . 9282'~9315'MD 6028'-6049'TVD See att.a.ched Well ;ervice Report (dated 10/23/87) for fracture da · .... 27. N/A PRODUCTION TEST · Date First Production I Method of Operation (Flowing, gas lift, etc.) · , Date of Test Hours Tested PRODUCTION F(~R OIE-BBL GAS-MCF 'wATER-BBL. 'cHoKE sIZE }GAS-OILRATIO TEST PERIOD I~ F'low Tubing Casing Pressure CALCULATED OIL-BBL' GAS-MCF WATER-BBL OIL~ GRAVITY-APl (corr) Press. 24-HOUR RATE I~ - 28. CORE DATA , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips· None ~...[aska 0/1 & Gas Cons. Anchorage · Note: Workover performed 7/27/87 & 10/2/87, Fractured well 10/23/87. .... Form 10-407 Rev. 7-1-80 WCz~/-5 :DAN I CONTINUED ON REVERSE SIDE Submit in duplicat~ 29. ~. 30. ~,. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8866' 5769' N/A Base Upper Sand 9004' 5855' Top Lower Sand 9201' 5977' Base Lower Sand 9406' 6109' 31. LIST OF ATTACHMENTS Well Service Report (dated 10/23/87) __ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge .~(~~~ TitleAssOciate Engineer Date /~-'~-~7 Signed // -- 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- lng 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 ARCO Alaska, In:-~ ~ Subsidiary of Atlantic Richfield Company w,,, CONTRAC~ ]T~O 'REMARKS'"- //~(o // WELL SERVICE REPORT / IDATE /0 -..,-~-oc7 I-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp' I Chill Fact°r I Visibility IWind Vel'Report OF "F mil®$ knotl [,~gned STATE OF ALASKA AL, .<A OIL AND GAS CONSERVATION CO. ..ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown © Stimulate ~ Plugging © Perforate © Pull tubing Alter Casing ~ Other ~, WORKOVER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO A1 aska, I nc. RKB 96' Feet 3. Address 6..U. nit or. Pr~o. perty.n.a.me P.O. Box 100360 Anchorage, AK 99510-0360 ~uparuK K~ver unit 4. Location of well at surface 568' FNL, 1192' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1056' FSL, 1453' FWL, Sec. 2, T11N, RgE, UM At effective depth 982' FSL, 985' FWL, Sec. 2, T11N, R9E, UM At total depth 928' FSL, 506' FWL~ Sec. 2~ T11N~ RgE~ UM 11. Present well condition summary Total depth: measured 10115'MD true vertical 6573 ' TVD Effective depth: measured 9478 'MD true vertical 6156 ' TVD 7. Well number 1Y-10 8. Approval number 7-196 9. APl number 50-- 029-20934 10. Pool Kuparuk River Oil Pool feet Plugs (measured) None feet feet Junk (measured) Fill ~ 9394' feet 12. Casing Conductor Surface Length Size 80 ' 16" 2726' 9-5/8" 7294 ' 7" 2656' 5" Production Liner Perforation depth: measured 9282'-9315', 9234'-9262', 9213'-9218' true vertical 6028'-6049', 5997'-6015', 5984'-5987' , 8872'-9004' , 5773'-5792' Cemented Measured depth 300 sx AS II llO'MD -1250 sx AS III & 2726'MD 250 sx AS I 725 sx Class G & 7294'MD 250 sx AS I 900 sx Class G 9607'MD Squeezed liner lap w/165 sx Class G Tubing (size, grade and measured depth) 3-1/2"/2-7/8"/2-3/8", J-55/J-55/N-80, tbg w/tail @ 9145' Packers and SSSV (type and measured depth) Stimulation or cement squeeze summary N/A Intervals treated (measured) True Vertical depth 1'1~) ' '2VD 2199 ' TVD 4835 'TVD 6239'TVD RECEIVED 0il & Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Well History) Daily Report of Well Operations !~ Copies of Logs and Surveys Run [_ 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 Engineer (Dani) SW02/96 Date Submit in Duplicate 'ARC° Oil~and Gas Company Well History - Initial Report- Daily _ Inatmetlona:TPrepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only, District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK2351 NOrdic #1. Oporat6r:::~ :-- "-- ARCO- Alaska.. Inc. Spudded or-W.O; begun- IDate I ICounW, parish or borough North Slope Borough ltea~ orUnit ADL 25646 Title Completion AP1 50-029-20934 Date and dept.h.~:__ . _ Complete record for each day reported as of 8:O0:a..i~j.::_- - '.- · _ _ ~?¥~_?-~. ~:~-:-~:--: _, -, ._ _ . 7/18/87. IHour 1200 hrs. iState Alaska Well no. 1¥-10 IARCO W.I. Prior status If a W.O. 56.24% 7/22/87 7/23/87 7/24/87 ~!~'.:-;--~ "5" @ 9607 ' -Ji'i?''. 19525' PBTD, Prep f/manet- ra .... .. .. ' ' ' :(-~!i.::-10-.9 pp$ NaCi/NaBr '.: i:?~-(::~'-AccepC ri~ @~'1200 hfs,'7/18/87. ~ill well w/50 bbls Litesal · ' ~:L pill & 10.7 pp~ brine~ well flowiu$. Displ well ~o. 10.9 pp~ ' :~/-:-'brinel well dead. Iff) tree; ~I & ts~ BOPE. Pull tbs_ h~r. POH "~::~::~. w/3~" ~bg. LD 2-7/8" x 2-3/8" tbs; dropped ~on$ dis in hole. · i'i:/ - RU DA f/ma~ne~ rn. ~5" @ 9607~ ' 8765~ PBTD, Hill on pkr 10.9 pp~ NaC1/NaBr RIH w/4" magnet & retry ~ong die. RIH w/pkr milling assy, mill on 5" pkr. (Accum fluid loss = 129 bbls). 5" @ 9283' 10.9 Mill push 9607' , POH w/pkr ppg NaCl/NaBr pkr free, CBU & push fsh to 9005', POH. PU spear, RIH, fsh to 9283', POH w/pkr, (Accum fluid loss = 141 bbls). 5" @ 9607' Fill @ 9447', Circ well cln 10.9 ppg NaC1/NaBr POOH w/pkr & LD same. TIH, CO to top of 5" lnr, POOH. wsh fill to 9447' DPM, rev circ well cln. TIH, 5" @ 9607' Fill @ 9447', Att to isolate csg leak 10.9 ppg NaCl/NaBr Began losing fluid w/rev circ. Circ long way to cln up well, POH. RIH w/5" RTTS, set @ 6988'. Tst ann to 1300 psi; bled to 1050 psi in 30 min. POOH in 5 std increments & att to isolate csg leak. ,--'.. :"- ':" ~ ..[:....'-j L~ / fGa.tlta 0ii ~: Gas OeYm. The above is correct For fo}'m preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date __ ] Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Inatrucflons: Prepare and submit the "Final Report" on the first Wednesday after allowable has bean assigned or well is Plugged, Abandoned, or Sold· operation if space is available. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test la not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK2351 Nordic ~1 Operator . -ARCo Alaska~ Inc. ~ Spudded or W.O.i begun · :~. Co~Iete · Date and depth: . . : ::'}. :: 7/25/87~: : : ICoy North Slope Borough or Palish Lease or Unit ADL 25646 Title Completion API 50-029-20934 JA.R.Co. W.I. Date Complete record for each day reported IAccounting cost center code State Alaska lWell no, 1Y-10 56.24% 7/18/87 Iotal number of wells (active or Inactive) on this Dst center prior to plugging and I bandonment of this well' I our IPdor statue If a W.O. 1200 hrs. 5" @ 9607' Fill @ 9447', TOC @ 6571' DEM, RR 10.9 ppg NaC1/NaSr Isolate cs8 leak f/810'-752'. RIB w/BP, sec @ 6891' DPM. ND BOPE, chg out tbs head, Cst packoff. NU BOPE &tst, pull storm vlv. Retry BP. RU DA, set 5" EZSV @ 7050' WLM. RIH w/2-7/8" stinger & 7" RTTS, tat lap; ieakimg. Pull RTTS. RIH w/2-7/8" stinger on 3½" DP. Batch mx & sqz lap w/65 sx C1 "G" w/.8% FL-28, .3% CD-31 & .3% A-2. Hold press on sqz. ¥OOH w/stinger. RIH w/12 stds 3~" tbg, POOH, LD same. RIH w/192 its, 3½",'9.2#, J-55 BTC AB Mod tbg open ended w/TT @ 6009'. ND BOPE, NU & tat tree. Freeze protect w/diesel cap. RR @ 0600 hfs, 7/27/87. Old TD Released rig 0600 hrs. Classifications (oil, gas, etc.) Oil INew TD J PB Depth Date IKind of rig -7 / 27/87 I Type completion (single, dual, etc.) Single Producing method Olficial reservoir name(s) FlOwing Kuparuk Sands Potential test data Rotary 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 above is correct Signature ~ -- ~ // I Date __ ]Title For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, In( Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 11, .1987 Transmittal # 6020 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. 2Z-4 Dual-Zone PBU ~A'-Sand 7-14-87 2Z-4 Dual-Zone PBU 'C' Sand 7-14-87 2Z-12 Dual-Zone PBU 'C' Sand 7-2-87 2Z-12 Dual-Zone PBU 'A' Sand 7-2-87 2U-15 Pressure Buildup 5-28-87 2W-6 Dual-Zone PBU 'C' Sand 7-15-87 2W-6 Dual-Zone PBU 'A'~Sand 7-15-87 3M-9 Static Well Pressure Report 7-26-87 3M-3 Static Well Pressure Report 7-17-87 3M-8 Static Well Pressure Report 7-28-87 2Z-6 Static Well Pressure Report 7-21-87 2Z-8 Static Well Pressure Report 7-25-87 2U-6 Static Well Pressure Report 7-19-87 3I-9 BHP Report 7-16-87 2W-7 Static Well Pressure Report 7-21-87 2X-lO Static Well Pressure Report 7-17-87 2X-14 Static Well Pressure Report 7-17-87 2X-12 Static Well Pressure Report 7-17-87 2W-3 Pressure Buildup Test 7-4-87 2Z-2 Static Well Pressure Report 7-17-87 2Z-6 Static Well Pressure Report 7-13-87 2Z-2 Static Well Pressure Report 7-9-87 2Z-8 Static Well Pressure Report 7-13-87 3M-1 Static Well Pressure Report 7-13-87 3M-2 Static Well Pressure Report 7-13-87 1Y-lO Static Well Pressure Report 4-23-87 1Y-4 Static Well Pressure Report 4-21-87 1Y-4 Static Well Pressure Report 3-3-87 Receipt AcknoWledged: AUG1 3 1987 Alaska 0il & Gas Cons. Commission Anchorage Date: DISTRIBUTION: BP Chevron Mobil SAPC Unocal State of Alaska D&M ARCO Alaska, Inc. is a Subsidiary of AllanlicRichlieldCompany STATE OF ALASKA ALASK,. OIL AND GAS CONSERVATION COMM,_olON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend .'~ Operation Shutdown [] Re-enter suspended well Iq.. Alter casing % Time extension © Change approved program [] Plugging ~ Stimulate lq Pull tubing j~k,Amend order ~ Perforate~_,_.Other~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, inc. RKB 96' 3. Address 6.'Unit or Property name P. O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit feet 4. Location of well at surface 568' FNL, 1192' FWL, Sec. At top of productive interval 1056' FSL, 1453' FWL, Sec. At effective depth 1, T11N, R9E, UM 2, T11N, RgE, UM 7. Well number 1Y-10 8. Permit number 83 -51 9. APl number 50-- 029-20934 10. Pool Kuparuk River 0il Pool 982' FSL, 985' FWL, Sec. 2, T11N, R9E, UM At total depth 928' FSL, 506' FWL, Sec. 2, T11N, RgE;, UM 11. Present well condition summary Total depth: measured I 0,11 5 'MD feet Plugs (measured) true vertical 6573 'TVD feet None Effective depth: measured 9478 'MD feet Junk (measured) true vertical feet 6156'TVD None Casing Length Size Cemented Conductor 80' 16" 300 sx AS II Surface 2726' 9-5/8" 1250 sx AS III & 250 sx AS I Production 7294' 7" 725 sx Class C & 250 sx AS I Liner 2656' 5" 900 sx Class G Perforation depth: measured Measured depth 80'MD 2726'MD True Vertical depth 80 ' TVD 21 99 ' TVD 7294'MD 4835'TVD 9607 ' MD 6239 ' TVD RECEIV O 9282'-9315', 9234'-9262', 9213'-9218', 8872'-9004' ~'cJ 26 ~87 true vertical 6028'-6049', 5997'-6015', 5984'-5987', 5773'-5792' Alaska Oil & b~s ~,u~.o..~,.,,, .... ..... '~ Tubing (size, grade and measured depth) - /2", _ , cho a . N-80, 8rd f/6823'-72~1',2-3/8''3 ~.7~ ~-~, ~r~5 f~~s~f~82~j ~-~/8" 6 5~ Packers and SSSV (type and measured depth) , 5" Baker DB ~876 8', CAMCO TRDP-1AE SSSV ¢ 2169' 12.Attachments Description summary of proposal [] Detailed operations program ~/~BOPsketch 13. FAsptirm~ ~te~ ,dalt~j ~Q/r commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge (/ ,~~ Associate Engineer Signed _/., Title Date Commission Use Only (,JL~) 5A2/32 Conditions of approval Notify commission so representative may witness I Approval No. ~~ ~ Plug integrity ~ BOP Tost ~ kocation clearancel ~,~.~~ W - ~-~r,~'~j 7 by order of Approved by BY [~N~I[- ~. ~Jl~ ..... Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Kuparuk Well 1Y-lO Conversion to Selective Single Preliminary Procedure 1. RU wireline. Obtain BHP. 2. Move in and rig up workover rig. Kill well. 3. Nipple down tree. Nipple up and test BOPE. 4. Shear out of SBR. POOH and stand tubing in derrick. Install A/B modified couplings. 5. Pick up 3½" drill pipe and retrieve the packer. POOH. 6. RU wireline. Run CET. 7. Perform cement squeeze as necessary. 8. RIH and set retrievable bridge plug. Install 5000 psi wellhead and test casing. Retrieve bridge plug. 9. RIH with bit. Drill out squeeze cement. i0. Rerun CET. Reperforate 'C' sand as necessary. 11. Run GR/JB to PBTD. RIH and set permanent packer between "A" and "C" Sands. 12. Run 3½" single selective completion assembly. 13. ND BOPE. NU tree and test. 14. Displace well to diesel by reverse circulation. 15. Test annulus and tubing to 2500 psi. 16. Secure well and release rig. Anticipated Bottom Hole Pressure: 2900 psi Workover Fluid: NaC1/NaBr Brine YPAD/1Y-10 .. p ANNULAR PREVENTER 6 PIPE RAMS 4 BLIND RAMS 5 TUBING HEAD 2 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-:~000 PSI STARTING HEAD 3, 11"-3000 PSI X 7-1/16"-5000 PSI TUBING HEAD 4. 7-1 / 16" - 5000 PSI PIPE P. AMS 5. 7-1/16" - 5000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2.ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING BOP STACK TEST '""~":""' 2 ,.'~ '~o.p..'.7 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY ~~tE~. P~E~ETE~HINE DEPm ~HA~ ~EST PLU~ WiLL SEAr ANO SEA~ IN WELLHEAD. RUN ~N LOCK-DOWN SCREWS ~N ~. CLOS~ ~,~ULA~ P~EVEN~E~ AND C~O~ES A~ ~Y~,SS V~LVES ON ~HE MANIFOLD. ~. ~EST ALL C~PONENTS ~0 2SO PSi AND HO~D ~0~ ~0 M~U~ES. S. INC~E~S~ P~ESSUR~ ~0 ~aO0 PS~ ,ND HOLO ¢OR ~0 M~NUT~S. ~LEED TO ZE~O ~. OPEN ANNULAR P~EVEN~E~ AND CLOS~ PiPE ~MS. 7. ~NC~E~SE P~ESSU~ ~0 SO00 PS~ ~ND ~OtD ,~ ~0 M~UT~S. a. CLOSE V,LVES D~ECTLY UPSmE~M OF C~OKES. ~LEED ~OWNSm.~,M P~ESSU~E ~0 ZE~O PS~ ~0 ~EST WLVES. ~EST ~M~N~O U~EStED H~FOLD VALVES, ~¢ ~, W~H ZOO0 PS~ UPSmE,M W~TH ZE~O PS~ ~OWNSmE~M. ~L~ED S~S~, TO ZE~O 9. OPEN P~PE ~MS. ~ACKOFF P. UN~ JaNT ~ND PULL OU~ OF HOLE. CLUE ~L~ND R~MS A~D ~EST ~0 ~000 PS~ FOR ~0 M~NUTES, ~L~ED TO ZERO PSI. ~0. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO ~000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG dULY 28, 1986 ARCO Alaska, ! Post Oft Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 1985 Mr. C. V. Chatterton, Chairman .Alaska Oil and Cas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: Wel ! Action Date Performed on the 1F-4 Convers 1F-5 Convers 1F-8 Convers 1G-3 Convers 1G-4 Convers 1L-3 Convers 1L-5 Convers 1Q-8 Convers 1Q-12 Convers 1Q-14 Convers 1R-3 Convers 1R-10 Convers 1Y-7 Convers 1Y-10 Convers 1Y-15 Convers 1Y-13 Convers 2B-6 Convers 2B-8 Convers 2B-11 Convers 2B-12 Convers 2C-2 Convers 2C-4 Convers 2C-5 Convers 2C-7 Convers 2D-4 Convers 2D-5 Convers 2F-3 Convers 2F-4 Convers 2F-15 Convers 2F-16 Convers 2D-10 Convers 2D-16 Convers on on on on on on on on on on on on on on on on on on on on on on on on on on on on · on on on on 10/24/85 10/24/85 10/24/85 10/25/85 10/25/85 10/24/85 10/24/85 10/25/85 10/25/85 10/25/85 lO/26/85 lO/26/85 10/26/85 10/26/85 lO/26/85 10/26/85 11/5/85 11/5/85 11/5/85 11/5/85 11/6/85 11/6/85 11/6/85 11/6/85 11/6/85 11/6/85 11/2/85 11/2/85 11/2/85 11/2/85 11/6/85 11/6/85 _ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION UOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL []X OTHER [] 2. Nam/~fcOder~(~A, SKA' INC. 3. Add,ss O BOX 360 ANCHORAGE ALASKA · · · · 99510 4. Location of Well SURFACE LOCATION- 568' FNL, 1192' FWL, SEC. 1, T11N, RgE, UIt4 7. Permit No. 83-51 8. APl Number 50- 029-20934 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1Y-10 5. Elevation in feet (indicate KB, DF, etc.) 96' (RKB) 12. 11. Field and Pool KUPARUK RIVER FI ELD I 6. Lease Designation and Serial No. KUPARUK RIVER O I L ADL 25646, ALK 2577 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ' [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On October to a water conversion "C" sands. 26, 1985 Kuparuk well 1Y-10 was converted from a producer injector well as part of the full field waterflood effort. Water is being injected into both the "A" and RECE '¥ED ~-~ r'- , - -,r. ,~, - Alaska 0ii & Gas (;rms. C0mmJssi0rJ Anci 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KU PARU K Date Signed ~//~_~<.-4 ~,,~,~--~-" Title OPERATIONS COORDINATOR The space below for Commission use 11/15/85 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate I~,~, 7-1 ARCO Alaska, Inc. Post Office b.~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage Will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversiOns will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincere ly, · T. M. Drumm Kuparuk Operations Coordinator cc: J. _F. Beall TMD:ps:013 RECEIVED Ar~chor~e ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany STATE OF ALASKA ALASKA~'L AND GAS CONSERVATION O¢--~"MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL r-I COMPLETED WELL OTHER I-I 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 4. Location of Well N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. 99510 Perforate Stimulate Repair Well 7. Permit No. see attached 8. APl Number 50- see attached 9. Unit or Lease Name Ku~aruk River Unit 10. Well Number see attached Pull Tubing I6. Lease Designation and Serial No. see attached Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool (Submit in Triplicate) (Submit in Duplicate) [] Alter Ca'sing [] Perforations [] Altering Casing [] [] Abandon [] Stimulation [] Abandonment [] [] Change Plans [~ Repairs Made [] Other [] [] Other X~ Pulling Tubing [] (Note: Rep6rt 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). IO Pursuant to form :[0-403, it is proposed that the attached list o~^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approximatel.v 10/15/85. The second conversion to a line drive pattern will occur approximately :[2/15/85. Injection will be into the A and C sands. RECEIVED SE? 2 o 9B5 Gas Cons. commission Anchora.ne 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, /~ ~~~'~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 Approved Copy ~.®turrta~ / By Order of COMMISSIONER the Commission Date __ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 1E- 6 -26 IF- 2 - 4 - 5 - 8 1G- 2 - 3 - 4 - 5 iL- 1 - 3 - 5 - 7 -16 IQ- 1 - 2 - 7 - 8 -11 -12 -13 -14 IR- 3 - 8 -10 -13 1Y- 1 - 7 -10 -13 2B- 5 - 6 - 7 - 8 -- 9 -10 -11 -12 2C- 1 - 2 - 3 - 4 - 5 1 MARK:009 Permit 80- 78 82-166 81-211 172 132 162 82-138 149 161 83- 20 84-173 158 123 145 181 84-231 232 218 209 199 193 85- 44 45 85-177 73 96 150 83- 50 68 51 15 84- 4 22 24 28 27 29 35 38 83- 83 93 89 94 99 API ~ 029--20493 029-20840 029-20881 20846 20807 20836 029-20813 20824 20835 20908 029-21196 21182 21155 21171 21202 029-21247 21248 21234 21225 21216 21210 21306 21307 029-21406 21333 21351 21385 029-20933 20950 20934 20903 029-21067 21078 21080 21079 21082 21084 21089 21092 029-20962 20972 20968 20973 20978 Lease 25651 25652 25640 25659 25634 25635 25641 25646 !! 25548 25656 25655 I! I! 25654 !! & Serial ~ Convert Date 469 10/15/85 " 10/15/85 2578 10/15/85 " 10/15/85 " 10/15/85 " 10/15/85 2571 10/15/85 " 10/15/85 " 10/15/85 " 10/15/85 2585 12/15/85 " 10/15/85 '! 10/15/85 " 12/15/85 " 10/15/8.5 2567 10/15/85 " 12/15/85 " 12/15/85 '! 10/15/85 " 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 2568 10/15/85 " 10/15/85 !' 10/15/85 " 10/15/85 2572 12/15/85 2577 12/15/85 " 12/15/85 2662 12/15/85 2582 12/15/85 " 10/15/85 " 12/15/85 !' 10/15/85 2581- 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 2580 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 E.P 2 0 B~5 Gas Cons. Corem .... lap ARCO Alaska,- Post O!' .ce Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 5296 RETURN TO: ARCO ALASKA, INC. KUPARUI( OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHOkAGE, AK 99510 TRANSMITTED RECEIPT AND SEQUENCE OF PRESSURE DATA HEREWITH ARE THE FOLLOWING. ITEMS. PLEASE ACKNOWLEDGE RETU~q ONE SIGNED COPY OF THIS TRANSMITTAL. '~'1C-4'- 07-23-85 --~1C-5' 07-29-85 '~1C-5~ 07-30-85 ~-'iC- 6 ~ 07-25-85 '"-lC- 6 ' 07-24-85 ~-iD- 8 .... 07-30-85 ~lH-3- '07-30-85 --~iR-5. 07-05-85 -'-'la-6-' 07-06-85 ~'-lR-8 07-U~-85 '~iY-10- 07-27-85 ~iY-11- 07-28-85 ~ 2A-2 .--' 07-04-85 ~ 2S-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-U4-85 ' 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 J ~7-18-85 - 3B-11 07-20-85 ' 3B-12- 07-21-85 3C-!1~' 07-29-85 STATIC BHP CAMCO PBU DRESSER ATLAS P~U DRESSER ATLAS STATIC BHP CAMCO STATIC BHP CAMCO STATIC BHP CAMCO STATIC BHP CAMCO UHP & MISC. CAMCO BHP & MISC; CAMCO STATIC BHP & ~I$C. CAMCO STATIC BHP CAMCO END OF PBU DRESSER ATLAS 'C' SAND STATIC BHP OTIS PKESSUkE DATA OTIS 'A' SAND PBU OTIS 'A' SAND PBU OTIS PRESSURE TEST & NISC. OTIS 'A' SAND PBU OTIS 'A' SAND PBU OTIS 'A' SAND ONLY PBU OTIS 'A' SAND PBU OTIS FLOWING BHP & FLUID I.D. OTIS FLOWING BHP & TEMPERATURE OTIS BHP SURVEY & MISC. OTIS STATIC BHP CAMCO STATIC BHP & MISC. CAMCO STATIC BHP & MISC. OTIS BHP & MISC. CAMCO STATIC BHP & MISC. CAMCO BHP SURVEY & MISC. CAMCO STATIC BHP & MISC. CAMCO STA~E O~ 'AL'AS~A* SOHIO* UNION* ~.TULIN/VAULT RECEIPT ACKNOWLF. DGED: BPAE* B. CURRIER CIiEVRON* D & M* DZSTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON NOBIL* PHILLIPS OIL* NSK CLERK J. RATRMELL* - ARCO Alaska. I~c. is a S~bsidiary of Atla~ticRichfieldCompany EVENTS FROM WELL SERVICE REPORTS ARCO Alaska, Inc. Post Offic~.'~ax 360 Anchorag,.. ,laska 99510 Telephone 907 277 5637 Date: 1/03/85' Transmittal No: 4951 RETURN TO: ARCO ALASKA, INC. ATTN: Records Cler~ ATO-1115B ~. P.O. Box 100360 ~Deh~rage, AK 99510 ' ~/~ansmitted are the following items. Please acknowledge receipt herewith and return one signed copy of this transmittal. TORQUE TURN-a'PRTES~UkE' ~' TEMP: sURVEYS 1Y-16 12/15f 16/84 Gauge #6~009 1Y-10 12/17, 18/84 #64009 lA-8 12/10, 11/84 #64009 /cat : ...... _. . . Receipt Acknowledged: DISTRIBUTION B. Currier ~rill~ng W. Pasher BPAE Geology' G. Phillips Chevron Mobil Phillips Oil D & M NSK Ops. J. Rathmell Date: '~li~,,,,,~ v,, ~ a~ COrlS. Commission Anchorage State of AK Sohio Union Well Files ARCO Alaska. Inc. is a lubsidiary of AllanlicRichfieldCompany ARCO Alaska. Inc. .-- ; ~ 3-.'' - - ~ :x-- .o~f.-[ ;- :.:-... £~-.'-- 277 $£37 Date' 10/12/84 Transmittal No' 4761 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk 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. PBU SURVEYS & 1Y-10 Lynes 8/17/84 SEQUENCE OF EVENTS SIBHP 8/17/84 /cat Receipt Acknowledged' F.G. Baker P. Baxter BP;~ Chevron Date: knchora~jfi DISTRIBUTION D&M W.¥. Pasher C. R. Smith 'Dritti 'ng~~ GeoSogy Mobil G. Phillips Phillips Oil J.J. Rathmel] State of Alaska Sohio Union NSK Operations R & D Well ~iles ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 9, 1984 Mr. C. V. Chatterton State of Alask~ Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached are Sundry Notices of Intention following Kuparuk Wells' 2C-1 Mud Flush 2C-2 Acid Wash 1Y-2 Acid Stimulation 1Y-10 Acid Stimulation 1Y-15 Acid Stimulation 1F-10 Perforate "A" Sand 1F-11 Perforate "A" Sand 1F-12 Perforate "A" Sand for work on the If you have any questions, please Charl es K. House Kuparuk Operations Coordinator CKH/kmc Attachment (In Triplicate) call me at 263-4527. ARCO Alaskb. tr~. is a subsidiary of AtianticRichiieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC, 3. Address P, O. BOX 360, ANCHORAGE, ALASKA 4. Location of Well SURFACE LOCATION' 568' FNL, 1192' T11N, R9E, UM 99510 FWL, SEC. 1, BOTTOM HOLE LOCATION' 928' SEC. 2, T11N, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 12. FSL, 506' FWL, 7. Permit No. 83-51 8. APl Number 50-0 ~9-20934 9. Unit or Lease Name KUPARUK RIVER UNTT 10. Well Number 1Y-10 11. Field and Pool i lvl KUPARUK RIVER FIELD · Lease Designation and Serial No. KUPARUK RIVER 01 L (RKB) ADI 25646; Al K 2577 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate )J~] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (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). The A and C Sands are to be acidized with acid flakes) for diversion. A CTU will perforations only and then rig down. The the C and A sands through the completion string using for diversion into the Lower Sand. The CTU will stand well with N2 if necessary. Requirements: 12% HCl Nitrogen Diesel Benzoic Acid F1 akes Fluid 12% HC1 acid and BAF (benzoic spot acid across the A Sand acid pumpers wi l 1 acidize both a 9000 BAF block by to surge the ons 1353 gallons 6000 gallons (143 900 ~ Expected start date' January 1~ 1984 Subsequent Work Reportecl on Form No. ~ Dated __/.__/__ 14. lherebyT~rego~eandcorrec.ttothebestofmyknowledge. Signed V'-r-- '~"¢"- ~'i~~ Title KUPARUK The space below for Commission use 0 P E RAT ! ON S COORDINATOR Date Conditions of Approval, if any: ' ~."-""' C. Approved by ~"i/ LU[~,[[ COMMISSIONER Approved Copy Returned f/- By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate / ~JP~RI. JK EN~! NEER! FIG TRA~M I'FI-AL #~ TO: William VanAI en FRC~: D.W. Bose/Shelby J. Nlatthews Transmitted herewith are the fol lowing- PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - F! LM, T - T .AP. a~l~y Al'IN: SHELBY J, IVATRIB\5 - ATO/11 1 5-B P. O. BOX 100360 A~C]ADP, AGE, AK. 99510 Transmitted herewith are the followirx:j' PLEASE F.O-I-E- Bi- BLUELINE, S - SEPIA, F- Fl Uv~, T- TAPF,~~PY~ ///~iPT ACJq,D, VLEDSED: · PLEASE P~'4 REC_~IPT TO: /-v,~3:) ALASKA, Ik~. ATTN: S~LIEI_P-,Y J. MA-I-fl-iB,:,S - ATO/111 5-B P. O. 'EEc, OX 100360 ANODE, Al(. 99510 KUPARUK ENG I NEER I i',r__, TRANS~I'FrAL #/~,~ TO: William VanAlen ~. D.W. Bose/Shelby J. Matthews Transmitted herewith are the followincj. RECEI PT ACYd'~¥1 FF'~GED- ,~ · ARCO· PLEASE RETUPaN ~I PT TO: ALASKA, I · . , ATTN: SHELBY J FA'I-Fi-IB~ - ATO/111 P. O. BOX 100360 A~,/NSE, AK. 99510 ~.--_ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 1, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1Y-10 Well Completion Report Dear Mr. Chatterton' Enclosed are the well completion report and gyroscopic survey for 1Y-10. If you have any questions, please call Jo Ann Gruber at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG3L41'tw Enclosures ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany " ' "'~'~ STATE OF ALASKA ~'-'- 0 ~ I 6 I N A [ ALASKA ..IL AND GAS CONSERVATION C:....IMISSION WlZLL COMI:)LIZTION OR RECOMI:)LETIOH RIZI:)ORT AND LOG 1. Status of Well Classification of Service Well oILX~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-51 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20934 4. Location of well at surface 9. Unit or Lease Name LT['~C~.-'-~-~ Kuparuk River Unit 568' FNL, 1192' FWL, Sec. 1, T11N, R9E, UM Ti©NS1 At Top Producing Intervalj I VJ~,°,JFI~D r lO. Well Number 1056' FSL, 1453' FWL, Sec. 2, TI-IN, RgE, UH ISurf.~_ I 1Y-10 At Total Depth I~3. H. ~.~ ~ 11. Field and Pool 928' FSL, 506' FWL, Sec. 2, T11N, RgE, UM~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 96' RKB]ADL 25646 ALK 2577 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 03/23/83 04/03/83 04/15/83I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth wher, e SSSV set 21. Thickness of Permafrost 10115'MD,6573'TVD 9478'MD,6156'TVD YESJ~] NO []I 2158/ feet MD 1350' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/GR/FDC/CNL/Cal, Gyro/CBL 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 80' 24" 300 sx AS II 9-5/8" 40.0# J-55 Surf 2726' 12-1/4" 250 sx AS Ill & 250 sx AS I ,. 7" 26.0# J-55 Surf 7294' 8-1/2" 725 sx Class G & 250 sx A.~ I 5" 15.0# K-55 6951' 9607' 6-1/8" 900 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9282 ' -9315 ' 2-7/8" 2-3/8" 8792 ' 8765 ' 9234'-9262' 3-1/2" 9213'-9218' 4 spf 26. ACID, FRACTURE, cEMENT SQUEEZE, ETC. 8872'-9004' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A -- 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL cHoKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow TUbing Casing Pressure CALCULATED ,, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor~) Press. 24-HOUR RATEI~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , None . . Form 10-407 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 GEOLOGIC MARKERS MEAS. DEPTH 8866' 9004' 9201' 9406' TRUE VERT. DEPTH 5769' 5855' 5977' 6109' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, iGOR, 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 X,~'~' ~/~~~ Tide Area Drilling Engr. Sign ~ /~-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". _ _ P R~O.Q.U CT Z ON (INJECTION) TEST SUHMARY o. TEST DATA WELL: TEST DATE: - I WELL TYPE: Old _ ~ New ~_ Pzoduce~ Injector PERFORATIONS: PRE-TEST (If well TEST SUMMARY is currently flo~ AVG PROD (INJ) RATE AVO COR - WOR WHP .~ CHOKE /~,~ DATE e GO ACTUAL TEST DATA AYG PROD (INJ) RATE AVG COR AVG W.~ CHOKE /! 6/~ HP m HD / FT HP ~ SS TOTAL.~DD (INJ) TIME SHUT IN TIME m 60 FT HR HR MAJOR WELL EVENT HISTORY DATE START END 0'700 ./~ 'o rD .... · . . ~ '' EVENT . - ._ CUMULATIVE PRODUCTION TOTAL PRODUCTION (INJE TIME SINCE LAST MAJOR ( INJECT ION): CTION) TIME: 5HUI IN: ' CEIV£D DAYS Alaska. 0il & Gas Cons. O°mmis~.ion Anchorage 1Y-lO DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1400 hrs, 03/23/83. Drld 12-1/4" hole to 2741'. Ran 69 jts 9-5/8" 40 #/ft, J-55, BTC csg w/shoe @ 2726'. Cmtd 9-5/8" csg w/1250 sx AS III, 250 sx AS I. ND Hydril & diverter. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drlg 8-1/2" hole to 9810'. Ran DIL/SFL/SP/GR/FDC/CNL/Cal f/9430' thru West Sak sands. Cont. drlg to 10,115'. Ran 186 jts 7", 26#/ft, J-55, HFERW BTC csg w/shoe @ 7294'. Csg stuck in hole. Cmtd 7" csg w/525 sx Class G lead and 200 sx Class G tail. ND BOPE. Set 7" emergency slips. Instld 7" packoff & tstd to 3000 psi - ok. NU BOPE & tstd same. Arctic packed 9-5/8" x 7" annulus with 67 bbl Arctic Pack & 250 sx AS I. Drld FC, cmt to 7286', tstd csg to 1500 psi - ok. Drld FS & cmt to 7324'. Tstd form to 11.9 EMW - ok. Ran 66 jts 5", 15#, K-55, FL4S lnr w/shoe @ 96(]7'. Cmtd w/900 sx Class G cmt. Drlg cmt f/6822' to 6951' PBTD. Tstd csg to 2000 psi - ok. Clean out hole to 9478' PBTD. Ran Gyro f/surface to 9400' MD. Ran CBL f/9400' to surface. Perf 5" lnr w/Hyper Jet II guns. Run #1 9295'-9315' @ 4 spf Run #2 9282' -95', 9354' -62' @ 4 spf (9254'-62' did not fire) Run #3 9234 -9254' Run #4 8992 -9004', 9213 -18' Fi red Run #5 8972 -8992' Fi red Run #6 8952 -8972' Fi red Run #7 8932 -8952' (8932'-42' did not fire) Run #8 8922 -8942' (wrong gun fired first, did not perf 8932'-42') Run #9 8932 -42' & 8912' -22' Fi red Run #10 8902 -8922' Fi red Run #11 8882 -8902' Fired Run #12 8872 -8882' Fi red 8252 -8262' Fi red 1Y-lO DRILLING HISTORY (cont'd) Set pkr assy @ 8765', ran completion assy 3 jts, 2-3/8" tbg, 57 jts 2-7/8" tbg. Instld SSSV & tstd to 5000 psi. ND BOPE, NU tree. Tstd packoff & tree to 3000 psi - ok. Disp well to diesel, drop ball, set pkr & shear out. Test pkr, tbg & SSSV. Closed SSSV. Secured well and released rig @ 0330 hours, 04/15/83. HILL/DHiO F'AD',°Y, WELL NO: lA SIGMA/GMS dOB NO: AO4.83P0129 KUPARUK FIELD, NORTH SLOPE, ALASKA DATE RUN: lO-APR-83 SIGMA 300 NO: 76Sy~ F'ROBE NO: 58 FC RE.=.I GHT: ,-. ~,o · =, o.'.'.75 W R E,E:.OR*[L OF---E,C:LIF~EY. RADILIS oF CURVATURE METHOD ARCO ALASKA, INC. PAD-Y~ ELTL-'NO.'--tO~ ...... E~'OMAYOM.~~- KUPARL~K FIELD, NORTH SLOF'E, ALASKA NO: AO483F-~-:79 MEAoUREE DRIFT DRIFT. COURSE VERT I CALVERT I CAL SUBSEA DEPTH ANGLE D I RECT I ON LENGTH DEPTH SECT I ON TVD ...... FEET ............... D ......... i'4 ................ D .... -1'4 ....... F'~- FEET ..... FEE-, T FEET ('). 0 0 0 0 0. 0'. 00 0.00 -'B 6.00 ,::,:~MF'I_ITAT I ON F'~GE Ni'/.. 1 T-I-ME ,' ~, ~ 11 ' 22: '~'= ~...-~, · ..~,..I ~) ~'~ /X r-,r-, ~,.-, R E C: T n N G LI L A R C L 0 S U R E . B r',GLECq [ I- L./--. I I L.I.. I J-." I I ~..,,.., 0,00 0.00 0.00 0 0 . 0.00' %.1 n .L 1,,... # ,w;. *.., 200. C) 1':' S 6:3 55 W 100. 200 O0 0 28 104 O0 0 20 N 0;49 W 0 ~" :3 · .._~ N 67 1 W 0 26. · 300, 0 15 c.... 51 25 E 100. 300.00 0.50 204,00 0.1~.-, S 0.53 W 0.54 S 76 7 W · 0..:,'"°:, . '400: ........... O-"r" t--3--S 'a65--l"6--'E ........ i"0G~.' ........... 40¢--~0' .~ I 52 S 0 10 E 1 5~ =.:,C)C') 1 ~' 1 S 40 ' 8 W i C)O 499.99 0.8C) 4C)3. ........ 6'0~; ..... 4-"49-'"S-'~:3'-~'~-~ O~ ...... ~9~-8'~ ....... , 700. 9 11 S '"".,~ 42 W 100. 699.'05 18.[:2 603.05 12.48 S 13.61 W 18.46 S 47 _':,<). 'W 4.37 ' ' 50 S 41 W 4 :~c)0 1356 S 46 52 W 1.00 ..... 796 99 38 29 700 99 25.42 S '~'~ 92 W :38. 48 89 ------eO(~ ....... t 8"-t~'~'4~~ t~0~: ~' ~"~ .. ,.:67.,~8 1000 21 52 '' 52 53' W lC ,, ~86., S 47 47 W 4.62' 1200 28 ~ ~ 5= "~[' 'S 51 47 W 4.2z-; . . ..._, 2.w 67. 7o _ __ S . w . . A PETRO~NE GOMPANy 1500. 39 36 S 50 44 W 100. 1410.71 359.83 1314.71 222.70 S 283.19 W 360.26 S 51 49 W 0.~'C'=.., ' ..... ~-6OO'~- ......... ~.2--..-:36F~.--~ ........ i-~-~- · 100,' ~&,--,G..--~.~,~.---~9.~C)~..O .... S ~:~-~-.. 2800. 44 59 ~ 5~ 35 N 20C). ~629. 2000. 48 13:3 49 4 C) W 100. 1768 . ,r~-,_ .~ --"I ,'~,r, ---~,.=_-.1------,7-- c- .-,~-,(1~--t--2~ t.t t r,r, t c.~ dc. -.--., b ~--~ vv ~. '-.- -.- u d. '--' ' · '--' .' '-'0'" 5"" '-' , . ,.~. ._ ..:,5 .:, 50. :z~.=i_ W 10 0 . 1:3 9 4 .9. 9 ~_/-._ 2 .2 3 17 9 8 .9 9 5 41 . 10 S 2300 ~ - E; · ._ 4 1 50 19 W 100. 1954.39 942.47 1858.39 592.32 '2, 2--44}0,---~,4--~57-.-:~ 48--2~-W ~00. , 2C~1_o=._48 ,Jr'"")0~-_~-.-~.~--='-' 1~ ~Ym.-~8 · /-'~K ........... ':'<' ~ 2500. 54 51 S 48 11 W 100. 206~.97 1104-.84 1973.~7 d... ---- -..- -.~ m %.- -_--_. · '-... , · d.. d.· · d, .- -.- · 6 ~ -.- . . m · . 2.'700. 54 53 ~'._. 46 33 N 100 . .,_'-~'184 .951267 .1¢/. c, 0,o,.¢:~._ _ _. 9~ 2:300. 54 59 S 45 5(3 W 100. 2242.39 1348.16, 214/_-,. :39 2900,, 56--~ S-A~5----O-W---- ....... l ru-~ 22'?E:. .:,~.~=_~._.~,_~--,o "/~ '-'¢' ¢"= 2202. -.:-=~'¢' 707.55 1672.8:3 441.73:3 554.1:3 W 70:3.65 S 51 26 W .............. - ............. ~ ............... ~,I 1E~ W 67:3.2:3 W 863.77 S 51 13 W 735· 32 W 944.21 S 51 9 W 797.!2 W . !025.57 q 5! ! W 699.67 S 858.24 W 1107.30 S 50 49 W 754..65 S 9!8.82 N !JIBS. 00 S 50 .3/_.. W 810.51 E; 978.65 W 1270.70 S'50 22 W 867.17 S 1037.74 W 1352.36 S 50 ' 7 W 92~5.31 S ~rJ96~76 W !474.9'5 S 49 5! W 2. :39 2.00 0.95 1.77 - 0.25 0.66, O. 59 ,, , ARL. J ALASKA, INC. F.AD--Y-,--W EL~-'-NC4 ..... 1--0 .... E.~ .E~M~/-E,;M~.,-- KI_IPARUK F ~ ELD, NORTH~'.:,LrdF'E, ALASKA TDI It" , i ~-..-i.. I ' MEASI_IRED [RIFT DRIFT COI_IRSE VERTICAL VERTICAL SUBSEA DEPTH ANGLE DIREF:TION LENGTH DEPTH SECTION TVD 2 R E C: T A N G U L A R C L O S LI R E I~'u-.~LEG C O O R D I N A T E S r-JloTAN..E DIRECTION .SE'I, JERITY FEET FEET D , M DG/iOOFT · _-,00.) .... =, 5 .S 44 25 W 10C), 2352 10 151:3 03 10 .-,~._, .S 1156 10 W 1518 '~8 .~._, . . .:. 4~ 34 W 1 3200 57 19 ':' 45 34 N 100, '~"="' 90 1579,78 '~ ~ 90 O. .....~.~,:, ~.~/.-~, 1104, 64 S 1275, 85 N 1687.61 S 49 7 N ._,4 = .:,., 46 27 N 100 2512 70 1763,12 2416.70 1163.18 S ..... ~ 0,7':) 3300. ._,7 ~'~ S , , 133~.49 ~ 1771.78 S 48 .... ~7400., ......57.-51-..S.~+.....4.2-W..: ...... 1-~ .... ~~ 184~---~~~.2 [. '29 S : i 3'P7.90 N ! 855 ~ 26 3SO0. 57 31 S 46 47 W lC)C) 261?~ 56 1930 54~,~o~'=~"' 56 1279 20 ~' =~ ...... c, 14..,:/.45 W 1$/40.71 , 48 46 W O, ~ .... ...... ~bO0, ........ S~.-~-~-47-....20--~.~.¢~,----:~b. Tzl~,J4-~-~-.-~.~.~,.7~ ..... ~3~.~ S !520,.99 W 2024.72- E: 48 42 ~ ~ '-'" 3700. .. 7 .., ,:, 47 54 W 100. 2728 20 20~7 10 2632 20 1~' ~ S '='~'~' ~5 W 1 I u i i i ~ ~ iii] ~ ~i ~i. i · ~ ,~ 00 ~'- 21 '~ 3 07 48 .... ~ 1t S 47 55 W 100 2781 68 21R1.02 2685.68 1449 59 S 1~,45 67 W 8 :37 W 1 06 '-'~ = =~ S 4~ . u 2255,.24 ' ~'~~ -~S¢~LC: : 1708,2.7 H- C,':,~ c~, ~000' ~'-' ~I'28~7.~ ~ · " ~" ~6~ 78 c, · .,:, 12 S 46 52 N lC ~ 1770,35'N 2362 77 R 48 :~'2 ~ 0 33 i ~I , ~,, , ,, ~ ~ ~, i ~ ~ c 244.7 67 ...... ~i.0(,.~.-..-~8 ............ ~ ..... ~.--.4~-i.O W 1 2?:40. · :~.~ W ....... 8. . .. -,-) - ' 4.=,tO. 5~-: 1.0 S 45 42 N 1 4~.74 2& · ' N 26~7.42 S 1R_ N 0 21 10~~ - : 26 ,0~ N 270~--S -4.8.~ u ' '"' .. _ .,...,~,--~,~......~ ~ A PETROLANE COMPANY 4~)(') 57 45 ~' 45 38 W 100 3151 ~,6 2769.12 3055.56 1859 66 S 2075 80 W 2786 98 c. 48 S/ W 0 4:3 ~' ~' O. 1~ ...... 4700 57 '~:~: S ~6 0 W l f)O .... 29~6 . 2197.07 W ~'F/56.02 ...... · =,Z58.2~ .28 3162.2~ 1977 61 S 4800. 57 5 '.3 46 35 W '100. ':3312.16 3019.61 :3216.16 2035.79 S 2257.75 W 3040.19 S 47 58 W 0.75 ~(~, ~/- 5~ ~/' 51 W 100. oo/./~ 61 ~,~i~o~ ~ ~,r,o~ c,o ,= c,~,~o n~ ,.~ ~,~,a ~ . . . · ~' . · . ~'-~ . - - SAAb] 56 23 o 47 8 W 100 3421 57 3185.48 3325.57 2150.27 S 2380 11 W ._~07 5R S 47 54 W 0.5::: 5200.._5~._ 47 S 47 46 W 100. 3533.16 3350.17 3437.16 ~":'/:"~z. 36 S 2502.51 W 337:3,54 S 47 53 W 0, 33 ~S:C)r) M= 30 c. 47 M= .~,:' ~ .... 16 3493 Mo 2317 77 S 2563 72 W ' 3456.11 47 M~ W 0.30 ........ , ...... , W 100. 358? ~, ~oc,. . ~,_, . . S ......... ~00, ...... D5.-1 ~ g--~g-~W . -t~),- ..... ~L~$.,-.4:4.-~:~t7~,. ~ t ..... ::~(~---~7~.-l~}.~ 2~2B-~5 J J ~ '-' '-"-' 55AA. 54 2',-_-: c. 48 54 W 100 3704 03 3595.22 3608.03 2426.57 :~ ~'AF:6 45 W 3620 12 c; 47 sM W 0 81 -- . . ~, i i --_ . _ . .- ~. . - - ~),~-..~4--t~---,---~4--.~ .......... t-00, ...... 76=-~=.,, ...... 2~.7~..~1.-2---:~.~.~.--.247'P 9 !-~-- 274~-80 W . :. .. 5700. 5~ 37 S 49 . · _c: 17 W 100 RR21 07 3756.63 07 77 S 2RO'P O0 W 3782 25 c; 47 5G W 0 71 5800. 53 21 .S 49 47 W 100. 3880.56 38:36.69 3784.56 2584.'P3 '.~ 2870.16 W 3862.60 '.S 48 0 W 0.47 . ~,~,,', ~--, · _~,,--~:,.~ ..... t ..... 8--.Dt ..... 1-4 W ....... ARF:O ALASKA, I IIE. ..... PAD--y"r-WE. bL::=N0-::--tO ..... ~-C'~-0MA-/-OM'.'B-, ........................ ' '~ ,~,,..,,_:, r~,., - ,-,,.,,~',=,..:,r'"""~'="~'=:"~--':",.,'~ ~ ;- KIJPARUK FIELD, NORTH SLOPE,. ALAc, KA F'A L: E N I'] :3 ~' ¢; D~DGLEG MEASURED DRIFT DRIFT COUR::;E VERTICAL VERTICAL ::,LIB...EA IR E C T A N O U L A R C:. L. 0 S U R E DEPTH ANGLE DIREF:TInN LENGTH~ DEPTH. SECTION TVD C 0 0 R D I N A T E S I]ISTANCE DIRECTION SEVERITY ...... FEET ...................... D .......... M ............ B .... -M ..... F'EE~ ..........FEET-- .... FEET 'FE,_, · . , ,-,--, , ,_,.., D M hr-' L,..A(.~:-7.:,....., .,-..., , / 6000 .~ 18 S .=, 3904 41 ~6,_,3 1:3 c: 2.996.47 W 4022 '~'~-' "' .... 3 ..6 14 W 100. 4000 41 3'2'26 5& c, o. .:, 48 9 W 4 01 .................. 61-(:)t)"~- ....... .:,t-4-~-G--6£}--4 :~,:: 14 x G(+~---~£-~. :~..,~4,£'}-7..,-F7-t- ..... ~.'26~-,--~ .....~-2-7-2~~.-~~,--~4--W---44,..,.- ~ ~{-;-4.~t--~ ,.,. 6200 51 1.9 $ 61 7 W' "100 41-~- · '-' . · . ~,.~.46 415:3.52 4(.')27.46 2762.57 S 3132.60 W 4176 72 .:, 48 36 W 0 46 6o00....=,0 .F, 4 S 61. 18 W 100. 41. 86.23 4230.86 40.90. "'~- 2800.05 S 3200. c,~-'A W 4252 72 ~-' .=, 4,., 49 W 0.44 -- ~ ....... -... . - .- ,- z.-, --,~.-_,~_ o~, _,:. ,'.,,-~_,-, ~..i., ,~.-,o .'~ ,_'. 9.C:L ~ ~.l ;:~_,~/~___, ........ 6'4'~'~' ............ 50'""'""~4 $ -'6't'--D6-W ........... :L-G~:~-. ...... ~-24.9-~/:,-2 ...... -4--3G-'~.-64---44. 53, ....,:. ,-,-,.--... ,- ...-, ........ .,, ,., - ........... .-. .... · ""*~ ,'""'11 /-:,5(')0 49 54 c- 62 7 W 100. 4313 6.9 4383 81 4217 69 2873 26) S .=,o~,6.48 W 4403 11 S 49 16, W 0 ) ~ . m o.m # mm mm · me · , 660~.- -4,~,'- t5.'S-6t--1"9 W t-'()G'F----4..~78-zS'2 -445,C%--:'.3-7----4"28"2~.5:2--: 2~'0"~,-2~-7--S--~'~~ '~'"'"' "~' ~ ~"-'" '-"=' W 0,'--'° - .......................................... '"T-T · · m "T .,,' 4,.,,.,1.61 S 4.9 40 W 0·42 /::700. 49 '" ~' F;-: .... 346.9 76 W ~ c, 60 51 W 100. 444.3,~-~ 4~34 54 4347 ~2 2.945.83 E; . /-,~OF)_ _... 4:3 ~'>"~ S 60 ~,., W 100. 450~. 91. 4609.28 4413 . ~1 2.982.83 S..,~"~.~..,... .16 W 4625.4:3 S 4'2 ...=,1 W 0. :::6 ~'Yi, gGO, ..... '47 .~,,~. ,. -,~.... ., ~ ........... ~ ........ .,.,.. ........... . ,:;.,-~-?~,-,-,--~--.~.-,=,-.--~,.~.~ W -~.-. .- ,.- ,' ,-~----.-. .---- --- -. --- · - 'A PETROLANE COMPANY I 7500. 54 =¢ S "=~ .... ' · ~,) 61 54 W 1£)0. 4~z.,.~.34 5142.42 4863.34 3247 1.9 S 4001 30 W 5153 12 c. 50 56 W 1 '' ....... -76'G0,- ......... ~5 ......... 5--.~.--6:2--~,.~ W 100. 5016..--~,=-- :522~.~D..~-£~-~-7.~---~.:i-~5~.-~-8.---4(~74~87 ',; 523:3, 'r~ ~....~5- I ~ m 7700" 53 31 S 63 20 W 100" 5(:)75709 ~303"87 4.97.9·0.9 3321'84 S 4146·'7:0 W 5312"86 S .51 18 W 1,61 7800' 54 8 0 63 47 W 100 51:34·10 .5383"62 5038" 10 3'3'--7·7.9 S 4218 59 W 5391"77 S 51 2.9 W 0' 73 :,- ~ I W ~... ~,-, ~ ~o ~I ~,o,_ ~I ' °3°'~.3° S 4291 ~' '" ~ r,~ o ~:~ ~r. ,., · _,4=8 4.:,:,,_,.00 W 5550 4:3 S 51 ~1 W 0 ~'-' 50 W 100. 525C) 61 5154 61 -- 8C)0C). 54 35 c.._, 64 . 5543 .... 90 '-~ '-' 42 .= ~ '-'~ = · '- · -o~:~).. ...... ~,4.---,~_-66 30 . ! - -- ~23.91 .5~1~2 ~4~~ S- ~4~2~W 5629.63 S 5~ 3 W ! 8200. 5 12 67 :-~ :q · - .... · _4 S __ W 10C) 5:366.70 5703.34 5270.70 :349:3.73 S 4514.17 W 5708.23 '.3~'? 16 W 0 '~ 8300. 5:3 2.9 c; 68 M3 W 100. 5425.69 5781.83 5:329.6.9 35~3.68 c; .-~'-'¢~.,,: .... 16 W 5785.91 '::M'-' 9'~ W 1.2 8400 ....... ~'~--::: 70 52 u --,-,r, ~o~ ~c,~~ 5;]~~355!. i~~~_= u ~m/-'~' /-.~ S ~'~' A~ 8500. .=,'~ 2~. c.._, 71 34 W 10C). 5545.30 5935s.94 5449.30 3577.04 S 4740.28 W M¢~,o~..z .... 4.7 S 52 58 W · ._:t,~4. ~-,-~1 . ~ . -,..-.- , ~ .- . ,~ ........... ' - ~ - .. ....... :--:70c). :.:., -,/. c-74 :3 W 100 F,/-.6/-. 83 6¢)8&, 87 5570 83 2:6,24 05 ?. 4891 .98 W 6C):E:8.1:3 S 53 · ' "q W -- _ ........ _~ 44 W A:=:o¢) ........ 5L~ 1 :=; 7A '2 W 100 572:3 L]'-',:, 6160. 94-.=,A:~2.08 :3644.44 S 49~8.36 W 6161 /:,9 S ,-,,-,,-~r~ ~' ~ '-'"':' ~' !00 _. M ~' /- ~'"":-' ~ ¢; 366 !. ! o c. ~ ~naM 07 I:.l /-.?":;":: J3 c. _ .... --,s,<.,~--.-,---~_-,L---.~.,----e-7'F-'-l-¢-W- . -_7.~ 0,-(.-~ o=e-;.-*,--~-. -56-94,4:10 ..., ............. ~ 1.20 O_ '?~ 1.08 I .62 ARCO ALASKA, INC:. .;-F(AD--Y-,--WEL-t!--NQ~--1.C~S I G MA~/GMG F::~._IPARLIK FIELD, NORTH .=,LUPE,'-' ' ALAoKA C: ~'"l M P U T A T I Iii N P~ A A E' H' 0. T I ME ..... DATE 11:~'=~ '=' '~.. ,.".~=.., 20- APR-:::3 MEASURED DRIFT DRIFT COUR:::E VERTICAL VERTICAL SLIB'.E;EA R E C: T A N G I.I L A R C: L 0 .S U R E ]]~IALEG DEPTH ANGLE DIREr:TInN LENGTH DEPTH SECTION TVD C 0, 0 R D I N A T E S DISTANr:E DIRECTION '.::E~ERITY ...... FEE..T- ................ D ........ ~ ............... D---q~-----F EE~-- ............. F, EE-~ ........... F~E~ F-EE T F E E T F E E T D M .... D G /!.0DE-'[ 90¢)0. .=,1 50 S 79:31 W 100 ='-'=~ = =~ · .,,~..,~.05 6304 3'~ .JT..,~ 05 3675 =' . . ....... · .,,:B S 5122.16 W 6304 47 S 54 20 W 0 41 ~2AO. 51 1'3 S' :BO 57 W 100.' .~,~76., 47 6445, 77 =.o,:,,~ . ' . ..,=4 .-,=7 W 0 :E:4 ,., o ,,, ,., . 47 3702 51 S 5276.41 W 6445:36 S . '" · ~ "- S ' ~= ' =;~,c' 82 W 6515.25 ".E: 55 15 W 1 26 c/c, O0 ~ 0 J 81 ~:-~ W 100. 6039/89 6.., 14, 88 594~. 89 ..-:714.26. G ....... ~, . .... ~.4,L~.- ..... -4:-~. ........... ~,,-...~-g3...3EL~ ...... 1.O0~---~lOA~---65~2~L~ 6008, ~:~ ...... :~.~z~ / .. S/432 4. S/ 7 S '='~ :~o - '=' . ~ ......... W. 32. 6125.66 660~.28 .~,029.66 3726.75 c:.. 5452.37 W 6604.32 ... ~, . , ,PRO._IEC:TED TO TD 1011.5 MD 10115. 4.9 7 S ~'" ~' c. 57 37 W ! WhiOstock I ,, FINAL C:LOSURE - DIRECTION: S 57 [lEGS 36 MIN':'.~A4~JE.T~g~A~E~OMPANY ~-' F' ". . DI::,TAN_.E 7064 47 FEET O. O0 I PAD Y, WELL NO: 10 SIGMA/GMS dOB NO: AO48.3P0127 g'.'UF'ARUK FIELD, NORTH SLOPE, ALASKA --~,'-Id~7'~.~M~~--MD, SURVEYOR: ,~~F'~R'KO~' DATE RUN: 10-APR-83 S:]GMA 300 NO: 769, PROBE NO: 58. F_RE.:,IGHT;~.,:.'. 75 W A PETROLANE COMPANY . ARF:O AI_A.'SI<A, INC. '"i I I i ,.* I'"'o - i I....I_FQRI_IK F!ELD, NORTH .:kUFE ALASI<A C:ODE blAME TRUE : SL~BSEA MEAS;I_IRED VERTICAL MD-TVD VERTICAL R E C T A N G LI L A R C: L O S I_1 R E VERTI~E:AL .DEPTH · DEPTH DIFF DEPTH C O. O R D I I',1 A T E S DISTANCE DIRECTION 'I'HICKNES:.:; FEET- .... FE-E-T . FEET FEEq: FEET FEET _ri M ,, TOP UPPER SAND 8866.00 5768.94 3097.1 5672.94 3655.51S 5018.99 W 6209.10 S 53 56 W TOP LOWER SAND 9201.00 5977.10 3223.9 '5881.10 3702.65 S 5277.18 W 6446.57 S 5457 W BASE LOWER SAND 9406,00 6108,65 3297.4 6012.65 3724.59 S 5432.84 W 6586.98 S 55 34 W Wh;'pstOck A PETROLANE COMPANY Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, K / Y-lO ' Wel.~ Na~ and'Number' Reports and Materials to be received by: ~ ~'---/~ ~:~ Date .Required Date Received Remarks , , .. Complet_ion Report Yes. Well History Yes _Samples ~-- · , Core Description '/~' - -/ff/'//¢ _ Registered_ Survey Plat 7 ~- ~ ~ '- (~'~ ~(~"~ '~-~/-~/x( ' ~' ' ' ' Inclination Survey :,..:. Directi°nal Survey ~¢._~ ~/ ~ '~' :,. / Drill Stun Test Reports ~.~j(,: :;-'"~ ~ , . Production Test Reports 7~_,. .- ./ : > ~-~ .... :~ :~ ~-~ Logs Run- Yes ,_ , ~ ~- f-:.. =, -' Digitized Data ~c.~ q q"- ! 3 "' L43 /':' ...... ~ i~ KUPARUK ENGINEERING TRANSMITTAL ,~ 9~,¢~ TO: William V'~n Alen DATE' _~ ~.~~ y. Transmitted herewith are the following' FROM' D.W. Bose/Shelby J. Matthews WELL NAME- PLEASE NOTE~,~ F - FILM, T - TAPE, PC - PHOTOCOPY PLEASE RETURN RECEIPT TO/ ARCO ACASKA, INC Alask~ Oil & Gas rS,: ns. G.'.'mmission A'TTN' SHELBY J. MATTHEWS- AFA/311 Ar..shorage P.O. BOX 360 ANCHORAGE, AK. 99510 ~' ;'~ ARCO Alaska, Inc. Post office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 . ... May 16, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. ChattertOn: Bnclosed are the Monthly State Reports for the following wells' 1Y-16 1Y-1 1Y-2 1Y-3 - 1Y-8 1Y-9 Ravik State ~1 2Z-8 Ugnu ~PT #1 West Sak ~T #1 Thank you. Sincerely, District Drilling Engineer PAV/SH: tw Attachments STATE OF ALASKA ~ ALASKA L _ AND GAS CONSERVATION CC, .~IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling wellX~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-51 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20934 9. Unit or Lease Name FSL, 1192' FWL, Sec. 1, TllN, R9E, UM Kuparuk River Unit 4. Location of Well 568' at surface 5. Elevation in feet (indicate KB, DF, etc.) PAD 67', 96' RKB 6. Lease Designation and Serial No. ADL 25646 ALK 2577 10. Well No. 1Y-10 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Apri 1 83 For the Month of , 19__ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1400 hrs, 03/23/83. Drld 12-1/4" hole to 2741'. Ran, cmtd, & tstd 9-5/8". Drld 8-1/2". hole to 9810'. Ran logs. Cont. drlg 8-1/2" hole to 10,115'. Ran, cmtd, & tstd 7" csg. Arctic packed 9-5/8" x 7" annulus. Ran, cmtd, and tstd 5" lnr. Ran Gyro. Perf 5" lnr w/4 spf. Set pkr. Ran completion assy, disp well to diesel. Closed SSSV. Secured well & released rig @ 0330 hrs, 04/15/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 40#/ft, J-55, BTC csg w/FS ~ 27;~i~' w/1250 sx AS II I. 250 sx AS I cmt. 7" 26#/ft, J-55, HF-ERW, BTC csg w/shoe @ 7294', cmtd w/725 sx Ciass "G" cmt. 5" 15#/ft, K-55, FL4S lnr w/shoe ~ 9607'. Cmtd w/900 sx Class "G" cmt. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR/FDC/CNL/Cal. f/9430' thru West Sak sands. CBL f/9400' to surface. Gyro f/9400' to surface. 1 6. DST data, perforating data, shows of H2S, miscellaneous data ~y b e r J e t I I #1 9295'-9315' #5 8972'-8992' #10 #2 9282'-9285' #6 8952'-8972' #11 #3 9234'-9254' #7 8932'-8952' * #12 #4 8992'-9004', #8 8933'-8942' 9214'-9218' #9 8932'-8942', 8912'-22' * guns w/4 spf 8902'-8922' 8882'-8902' 8872'-8882', SEE DRILLING HISTORY 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~,~__~,f~. Area Drilling Engineer SIGNED TITLE DATE N E s~f "-- ' h f f OT --Repo/on ~s orrr/s required for eac calendar month, regardless o the status o operations, and must be filed in duplicate with the Alaska Oil and G~Conservation C)'ommission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 H I LL/MR1 0 Submit in duplicate KUPARUK RIVER UNIT 1Y-lO DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1400 hrs, 03/23/83. Drld 12-1/4" hole to 2741'. Ran 69 jts 9-5/8" 40 #/ft, J-55, BTC csg w/shoe @ 2726'. Cmtd 9-5/8" csg w/1250 sx AS III, 250 sx AS I. ND Hydril & diverter. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drlg 8-1/2" hole to 9810'. Ran DIL/SFL/SP/GR/FDC/CNL/Cal f/9430' thru West Sak sands. Cont. drlg to 10,115'. Ran 186 jts 7", 26#/ft, J-55, HFERW BTC, csg w/shoe @ 72~94'. Csg stuck in hole. Cmtd 7" csg w/525 sx Class A & 300 sx Class G. ND BOPE. Set 7" emergency slips. Instld 7" packoff & tstd to 3000 psi - ok. NU BOPE & tstd same. Arctic packer 9-5/8" x 7" annulus 67 bbl Arctic Pack & 250 sx AS I. Drld FC, cmt to 7286', tstd csg to 1500 psi - ok. Drld FS & cmt to 7324'. Tstd form to 11.9 EMW - ok. Ran 66 jts 5", 15#, K-55, FL4S lnr w/shoe @ 96.~7'. Cmtd w/900 sx Class G cmt. Drlg cmt f/6822' to 6951' PBTD. Tstd csg to 2000 psi - ok. Clean out hole to 9'478' PBTD. Ran Gyro f/surface to 9400' MD. Ran CBL f/9400' to surface. Perf 5" lnr w/Hyper Jet II guns. Run #1 9295'-9315' @ 4 spf Run #2 9282'-95', 9354'-62' @ 4 spf (9254'-62' did not fire) Run #3 9234 -9254' Run #4 8992 -9004', 9213 -18' Fired Run #5 8972 -8992' Fired Run #6 8952 -8972' Fired Run #7 8932 -8952' (8932'-42' did not fire) Run #8 8922 -8942' (wrong gun fired first, did not perf 8932'-42') Run #9 8932 -42' & 8912' -22' Fi red Run #10 8902 -8922' Fi red Run #11 8882 -8902' Fi red Run #12 8872 -8882' Fired !..,.~,~ ~ ~.:': '~ ~- 82521-8252' Fired ..... ~,, -: :.. :~,.. ,, 1Y-10 DRILLING HISTORY (cont'd) Set pkr assy @ 8765', ran completion assy 3 jts, 2-3/8" tbg, 57 jts 2-7/8" tbg. Instld SSSV & tstd to 5000 psi. ND BOPE, NU tree. Tstd packoff & tree to 3000 psi - ok. Disp well to diesel, drop ball. Closed SSSV. Secured well and released rig @ 0330 hours, 04/15/83. KUPARUK RIVER UNIT , SEqU£NCE OF EVENTS 'WELL: )~- -7 DPERATIDN: ARCO REP: EVENT ,.,---, STATE OF ALASKA ---.,. · ALASKA L _ AND GAS CONSERVATION CC. AISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS,, . I1. Drilling well XI~ Workover operation [] '~/~. _/~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, AK 99510 4. Location of Well atsurface 568~ FNL, 1192' FWL, Sec. 1, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. PAD 67', 96' RKB ADL 25646 ALK 2577 7. Permit No. 83-51 8. APl Number 50-- 029-20934 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1Y-10 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. March ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1400 hrs, 03/23/83. Drld 12-1/4" hole to 2741'. 9-5/8". Drld 8-1/2" hole to 8931' as of 03/31/83. Ran, cmtd, & tstd SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 40#/ft, J-55, BTC csg w/FS @ 2751 w/1250 sx AS II. 250 sx AS I cmt. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run CBL ~ 5000' Gyro 8931' to surf 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTfi--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed irfduplicat~ with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 H I LL/MR4 Submit in duplicate 1Y-lO DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1400 hrs, 03/23/83. Drld 12-1/4" hole to 2741'. Ran 69 jts 9-5/8" 40 #/ft, J-55, BTC csg w/shoe @ 2751'. Cmtd 9-5/8" csg w/1250 sx AS III, 250 sx AS I. ND Hydril & diverter. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drlg 8-1/2" hole to 8931' as of 03/31/83. HILL/DH3 KUPARUK ENGINEERING TRANSMITTAL #_~__~_~ TO' William Van Allen FROM' D.W. Bose/Shelbs J. Matthews Transmitted herewith are the following- PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM,~PC,- PHOTOCOPY __ RECE I~CKNOWLEDGED: /~q:~LEASE RETURN RECEIPT TO ARCO ALASKA, INC. · DATE' AT.TN: SHELBY J.. MATTHEWS - AFA/311 P.O. BOX 360 ANCHORAGE, AK. 99510 Commissioner FROMEdgar W. Sipple, Jr -~~' Petroleum Inspector MEMORANDUM State of Alaska FI hE NO: TELEPHONE NO: SUBJECT:BOPE Test on ARCO ' s Kupar uk 1Y-10 Sec 1 Tl l~-], R9E MUM. Permit No. 83-51 Parker Rig 141 Thursday March 24, !9~83: i arrived at ARCO's Kuparuk 1¥-10 Parker Rig 141 at 12545 p.m. The Drilling Rig was in the process of finishing the hole. .saturday_,_ March 26~_ !~983: The BOPE test commenced at 4:30 a.m. and was concluded at 6:05 a.m. There were no failures. I filled out the AOGCC BOPE inspection report which is attached to this report. In sumner, I Witnessed the BOPE test on Arco's Kuparuk 1Y-10 Par~r Rig 141. 02-00IA(Rev. 10/79) ,- O&G 4/80 STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATIOU COMMISSION B.O.P.E. Inspection Report Date ~'~--- ~ (~ '- ~-~ ' Well ,, Location:. Sec j T Drilling Contractor Rig # . Representative Permit ~ ~ 3 9~ Casing Set Representative Location, General Well Sign General Housekeeping Reserve pit Rig Ow. BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valv~'es Test Pressure Check Valve uO O ACCUMULATOR S'YS TEM Full Charge Pressure ~oo ps.ig Pressure After Closure ~ ~0 ~ psig 200 psig Above Precharge Attained:-0-'rain $'! sec Ful~ Charge Pressure Attained: ~ min 0~ sec Cqntrols: Master O~ Remote ~W~ Blinds switch cover~~-% Kelly and Floor Safety Valves Upper Kelly ~ ~/Test Pressure Lower Kelly ~L' ~' Test Pressure Ball Type . D~ w' Test Pressure.. 000 Inside BOP Oi( W' Test Pressure Choke Manifold o~~'' Test Pressure NO. · Valves No. 'flanges Adjustable Chokes I ,4~ %- lydrauically operated choke. Repair or Replacement of failed equipment to be made within'IV/,~ day§~4-1~~"a ' Inspector/~C~ssion office notified. Distribution orig.' - AO&GCC cc - Operator cc - SuperviSor. March 17, 1983 Mr. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 ' .~nchorage, Alaska 99510 Re~ Kuparuk River Unit IY-10 ARCO Alaska, Inc. Permit No. 83-51 Sur. Loc. 568'Fl~L, 1192'~]~, Sec. !, TllN, R9E, Btm~ole Loc. 384'FSL, 199'F~L, Sec. 2, TllN, R9E, Dear Mr. - Kewin: Enclosed is the approved application for permit to drill tile above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmet~r surveys. ~nY rivers in Alaska and their drainage systems have been classified as important for the spawning] or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may De contacted by the Habitat Coordinator's Office, Depar~ent of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Cna~ter' o 3, Article 7 and .ne regulations pronulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to con, cueing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout Mr, JeffreY B. Kewin Kuparuk River Unit IY'10 -2- March 17, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. 'Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of 'suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very~ truly yours, C. V~ ~atterton Chai~n of MY O~DSN O~ 1~5 Alaska Oil and Gas Conservation Co~ission Enclosure ccz Department of Fish & Game, Habitat Section w/o encl. Department of Envirorunental Conservation w/o encl. be ARCO Alaska, Inc. '"'"~' Post Office B(,_ .,60 Anchorage, Alaska 99510 Telephone 907 277 5637 March 9, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Dear Mr. Encl 0 Kuparuk 1Y-10 Chatterton: osed are: An application for Permit a $100 application fee. to Drill diagram showing the proposed of the wellbore. of o A projections o A proximity plat. o A diagram and description system. o A diagram and description of the Since we estimate~:'~pudding this well prompt approval will be appreciated. If you have any questions, please call Sincerely, .~ A~~eaB~~neer JBK/JG2L25:sm Attachments the Kuparuk 1Y-lO, along with horizontal and vertical surface hole diverter BOP equipment. on March 21, 1983, your me at 263-4970. RECEIVED Alaska OJJ & Gas Cor~s, Curnfaissior~ Anchorage ARCO Alaska, inc. is a subsidiary of AtlanticRichlieldCompany · "'~'. STATE OF ALASKA .... , ALASKA fu,L AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~0( DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE ~ MULTIPLE ZONE [] 9. Unit or lease name Kuparuk River Uni~,;¢¢?, 10. Well number 1Y-10 2. Name of operator ARCO Alaska, Inc, 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 568' FNL, 1192' FWL, Sec. 1, T11N, R9E, UN At top of proposed producing interval Target @ 6064' TVD: 900' FSL, 1100' FWL, Sec. 2, T11N, R9E, UM At total depth 384' FSL, 199' FWL, Sec. 2, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) ! 6. Lease designation and serial no. , PAD 67', RKB 96' ~ ADL 25646 ALK 2577 11. Field and pool i{~O Kuparuk River Field ..~ Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 33 mi, NW of Deadhorse 16. Proposed depth (MD & TVD) 10332' MD, 6620' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 14. Distance to nearest property or lease line miles 199' FWL ~ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 55 o (see 20AAC25.035 (c) (2) 15. Distance to nearest drilling or completed 1Y-11 well 607 @ surface feet 18. Approximate spud date 03/21/83 2645 psig@ 80°F Surface 3010 psig@ 590F, ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing Weight 4" 16" 65.5# 2-1/4" 10-3/4" 45.5# 2-1/4" 9-5/8" 40.0# 8-1/2" 7" 26# 22. Describe proposed program: CASING AND LINER Grade Coupling Length H-40 PEB I K-55 BTC I J-55/ BTC I 2501 ' HF-ERW K-55 BTC 110304 ' I SETTING DEPTH MD TOP TVD 80' 29' I 29' I 41 ' 29 ' 29 ' 70' I 70' I 28' I 28' I MD BOTTOM TVD 109' 109' 70'I 70' 2571'12200' 10332' 6620' QUANTITY OF CEMENT (include stage data) ±200 c.f. 1100 sx AS III & 250 sx AS I 445 sx Class "G"extended 440 sx Class "G" neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 10332' MD, (6620' 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). Expected maximum surface pressure will be 2645 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. 1Y-11 will be 60' away from 1Y-lO @ the surface. There are no closer wellbores anywhere downhole. Top of cement for the production string will be placed ~ 2986' MD, approximately 500' MD ~. 23.1herebycertifythattheforegoingistrueandcorrecttothebest of my knowledge above top of West Sak Sands. ' ~"*']'-.~ The space b~iCw~fl~O-f/om/ssi~n use/ -- Area Drilling Engineer TITLE DATE CONDITIONS OF APPROVAL Permit number Samples required Mud log required []YES .~NO []YES E~No . .- Approval date GRU2/PD10 APPROVED BY Form 10-401 D~,, -7 I on Directional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE ~rch 17, ]983 by order of the Commission Submit in triplicate . ............ , , ] ~ ........ ..... I~ I II~ ......... : ~ ' ' ...... I i i : ] , l z_L_~ ~-H ~ ~ -x~*~-:~r~c ~.:~,j ~i:~.--~s~o-=-x---J ........ :[ ::.:' .': x:¥:.:u::.::: ::::::::::::::::::::::::: ' ' ~ [ t J, j j j i Jill :,::.~=j, ,:: :_~ :-~, ~ JJii. ..jilj [jji ' ,~ .il ::,:~ j I , ~ ij t : ': ..i~i:', ~ ':ii, ,:::~ : : ~ :~,-- ,~!j ~[UU ! J_ . . .... .., : ::,,.... I ~ 1 i I j ! ~ i Jl ! i J i : [ iiI : J J ~ [ ~[]1 ; il ~ ' : : ' ' ~jJ!, ,~ , ,i : ,i ~ ii, , lii, i, , ,i~,' il'J~ , ,: , iiii ~ . i , ,iii :~i~i, : : ti, ~'~' ~iJ~' ~ ~'~,,~. ~- Surface Oiver'.er S~/s:em !. ~,6" - 2000 psi Tanzco starting head. 2. Tankco quick connect assy. 3. 16" x 20" 2000 psi douDie stuQQed adapter. 20" ~,.SO0 psi drilling spool w/!O" side outlets. 5. 10" b~ll valves, hydraulically actuated, w/lO" lines to reserve pi:. Valves ~o open automatical ly ~pon closure of annular 6. 20" ~ c~,~ psi annular preventer. ' 7. 20" bell nipple. 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 'every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. .Do ,not shut in well under any circumstances.' ' 16" Conductor ANNULAR PREVENTER 9 BLIND tL~'q S -- PIPE I~AMS 7 (- SPOOL ) PIPE ARMS ~ 5 CSG HD k,,1 D iAGP~M 13-5/8" 5000 PSI RSRRA BOP STACK 1o 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 13-5/8" - SO00 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7, 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI Will( 1S00 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER. ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8' BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. .CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND' SEAT IN WELLHEAD. RUN IN LOCK DOWri SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR I0 MINUTES. " 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND' ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI, g. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE DOPE DAILY. g- i i ii, i i ANNULAR PREVENTER 11 . BLIND RAMS'. I0 - PIPB ARMS ) 9 f · ' ' ~.~~~ )RILLING ' . PIPE ARMS 7 TBG HD 5 DIAGRAM ~2 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 7-1/16" - 3000 psi tubing head 4. 7-I/16" - 3000 psi x 11" - 3000 psi double studded adapter 5. 1I" - 3000 psi x 13-5/8" - 5000 psi spacer spool 6. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi drilling spool w/choke and kill' lines 9. 13c5/8" - 5000 psi pipe rams- lO. 13-5/8" - 5000 psi blind rams 11. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1o CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABL£ LOWER LIMIT - IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 10. 11. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTI.C DIESEL. 2. CHECK THAT' ALL HOLD DOWN SCRE~dS ARE FULLY RETRACT- ED. PREDETERMINE DEPTIi THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR. PREVENTER AND_CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. ?. INCREASE 'PRESSURE TO 3000 PSI AND HOLD' FOR 10 MINUTES; 8. CLOSE VALVE50IRECTEY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLO VALVES, IF ANY, Will/ 3000 PSI UPSTREAM OF VALVE ANO ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. OPEN. BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSt FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSII'ION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE DOPE DAILY. PHASE II RESERVE PIT .. ~00 RESERVE ' PIT . . ' - ' , ' .:.. ,,,- . · RESERVE PIT RESERVE- PIT ~ NOTES; . PHASE I 9. Y=5974755.35 X= '530921.60 LAT. 70° 20'31.5137". LONG, 149° 44t 56,599" 568tFNL, 1252' FWL I0, Y= 5974755.:57 X= 530861,81 LAT, 70°ZO' 31,5163" LONG, 149°44'58.345" 568' FNI~, 1192' FWL I I.' Y= 5974755. 40 X= 530801,57 LAT. 70° 20' 31, 5190" LON~. 1'49° 45'.0,0.,105"' 568 FNL~ 1132 FWL J I. ALL Y ~ X COORDINATES ARE ALASKA .STATE PLANE,ZONE 4. 2, DISTANCES TO SECTION LINES ARE GEODETIC, 3. SEE REF, DWG, 22988, SHT. 7Y-12-3OOI,REV. 7A, 4. DRILL SITE AND Y (~ X COORDINATES ARE BASED ON MONUMENTS I,Y WEST AND I.Y MIDDLE BY LHD A~SOCIATES. · ~.,Y:..' ' .P~ -",.q U k. ~~' .~.~ -~.'~ % , ~e~eeeeee~eeeeeeee~ r~' · ~ ~& ~ DAVID FILUCCI ' r ~ SURVEYOR'S CERTIFICATE I.HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND X= 530741.58 , ~[~SJO~~~ ". .ALASKA, AND ~AT THIS PLAT REPRESENTS A SURVEY MADE LAT. 70020' 31.5206 '~%~ ' ' UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE LONG. 149°45~ 01,8~" ' ' ' ' 568'FNL~IO7~'FWL.. CORRECT AS OF JANUARY 30~1983. 13. Y=5975115.63 15. Y=5975115.51' ~. ~~~~(~ ARCO Alaska, Inc. X= 5~0741.~4 X= 530861.,~7 ' . .. Kuparuk Project North Slope Drilling LAT. 70°Z0'35.0~4~'' LAT. 70°20 3S.OSe7 ~~ D.S. IY CONDUCTORS LONG. 149o 45'01.813" LONG, 149o44' 5&315" /' '' ' Bali 2 14. Y=5975115.61 16. Y=5975115,36 · . PHASE I x= 530801.96 x= 53o921.68 . - LAT. 70 °~0' 35.0621" LA~ 70°~0'35.0547" aSSOB .a,e' ,=.'.' ~08'FNL~ 1134'FWL ~08' FNL~I254'FWL I drawn by'J.B./D.E dwg. no. NSKg.05 d.17 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well ITEM APPROVE DATE (1) Fee ....... ~2 thru 8) 1, me 3. 4. 5. 6. 7. 8. (4) Casg_~(. ~, ~, ~Y- f7-~ (12 thru 20) (5) OPE (21 thru 24) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO , Is the permit fee attached ............ . ............................. // __ Is Well to be lOcated in a defined pool .... Is well located proper distance from property line ................ 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 .............. Is operator the only affected party ....................... .......... Can permit be approved before ten-day wait ............. ; ............ Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons .., .................. Will surface casing protect fresh water zones .... Will all casing give adequate safety in collapg~i ;~ngig~ ~ ~g[g;][ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached . Does BOPE have sufficient pressure rating - Test to ~~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. REMARKS Additional requirements ............................................. ~ Additional Remarks: /-~.-~:~, C~_-t../~;~,~ L~v OAt /.~]~ [)~,~ ~ I Geology: E.ngi~g~r .i,n g: ,, rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXi No 'special 'effort has been made to chronologically organize this category of information. o. .... L I $ 'll,Z p t'~ VEI~ IF ICAT ] (lin I, ISTI. NG ~E O10,HO2 VE[4IF'!C/~1 ICltq LISTIt~t(; P~,GE , REEL HEAD'~:R ER, V 10~. NA~E aTE :8]gO4/ 5 EEb NA~E : DNTINUATICN ~ :O1, REV IOUS D~4MENTS :bI[~A~'~Y TAPE # TAPE HEADER ** ERVI, O~ NANE ::[ ERVIC ATE 18~gO4/ 5 ~IGIN UNTI mUATION ~ : 0 REV~'I. OUS TAPE , FIbE HEADER IbE NAME :SERVIC.OOI ERV IOl~ NAIVE ~RS IDN # ATE : aXI~U~t L, EN~TH ] bE TYPE ~EVlOUS ~IbE NEM CgNI'F ~IT5 N : AIgCL1 ALASKA N : 1Y-lC N : KUPAIqUK A N G: § E ECT: 1 OLIN: N, SL, tJPE TbT: ALAS~ A TRY: , COMMENTS ** 1 N C UNIT TYPE 000 000 OO3 000 000 000 000 000 000 CATE DO3 OG0 ~)00 000 000 000 000 000 000 016 0O6 OO8 0¢2 30~ 002 OOB 0O6 004 CODE O65 O65 065 0~5 065, O65 O65 O65 065 VP 010..H02 V~]'RI. FIC~TIt'J¢~ [ I'STI[.!gr P~G~ ~, ALASI~A COMPUTING CENTER O~PAN~ = A'rb~NTB( R3( H~ I,ELD COMB/NY ELb = IY~I 0 OUNTY = ~O}~I,H S'L[3PC ~(.)ROUGH U.N #1, :[ATE I[;CGGEE: I-API~-B3 AS1NG = q. 6~5" SURF,ACE YP~. FLU'I.)! - X-gl POI~YMF~R IT SIZE = 8.5" EN$ITY = 10.2 I$Ci35IT Y = 45.0 LUIO IJ068 = 5.5 C3 T 2727 ' = 2.720 0 79,0 DF RI~iI~' = 2.790 @ ]~.0 I~F i~NiC = ?..190 0 79,0 DF i~,,M AT ~l-}-!'l' = 1..52~ ¢ 147.0 D~ ATR1X SANOST£INE DATA FORMAT RI.;'CORD ~.~ NTRY ~ b VP OIO,H02 VERIFI. 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