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182-077
MEMORANDUM TO: Jim Regg L�Z Zoyv P.I. Supervisor l FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, January 24, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-22 PRUDHOE BAY UNIT 13-22 Src: Inspector Reviewed By: P.I. Supry rbc-- Comm Well Name PRUDHOE BAY UNIT 13-22 API Well Number 50-029-20749-00-00 Inspector Name: Adam Earl Permit Number: 182-077-0 Inspection Date: 1/23/2022 - InSp Num: mitAGE220124094648 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-22 - IType Inj 1 w ,ITVD 8222 Tubing'1 1389 - 1387 - 1386 - 1387 PTD 1820770 - IType Test] SPT 'Test psi 1 2056 IA 699 2165 - 2115 - 2101 BBL Pumped: 1-5 - Returned: 1.5 - OA 0 0 0 0 iBBL -- ---. -- -t---- Intervall 4YRTST �P/F P - Notes: MIT IA Monday, January 24, 2022 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,January 17,2018 TO: Jim Re P.I.Supeerviisor ` �1 1//1115 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 13-22 FROM: Jeff Jones PRUDHOE BAY UNIT 13-22 Petroleum Inspector Src: Inspector Reviewed By: nn P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-22 API Well Number 50-029-20749-00-00 Inspector Name: Jeff Jones Permit Number: 182-077-0 Inspection Date: .1/13/2018 Insp Num: mitJJ180113114609 Rel Insp Num: • Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-22 Type Inj W 'TVD 8222 - I Tubing li 668 - ' 669 i 668 668 ' PTD 1820770 Type Testi SPT Test psi 2056 IA 61 2250 2206 - 2196 - BBL Pumped: 3.9 ' BBL Returned: 2.8 ' OA 40 42_ 41 _ 41 Interval 4YRTST P/F P Notes: I well inspected,no exceptions noted. V SCANNED ; Wednesday,January 17,2018 Page 1 of 1 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: 5e i— /BP 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 182-077 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ® 6. API Number: 50-029-20749-00-00 7. Property Designation(Lease Number): ADL 0028315 8. Well Name and Number: PBU 13-22 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 9975 feet Plugs measured 9623 feet RECEIVED true vertical 9276 feet Junk measured 9208/9897 feet JAN 13 �Un�E Effective Depth: measured 9623 feet Packer measured 8904 feet true vertical 8932 feet Packer true vertical 8234.67 feet A GCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 81 20"91.5#H-40 40-120 40-120 1490 470 Surface 2488 13-3/8"72#L-80 39-2528 39-2527 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9460-9480 feet 9566-9586 feet 9592-9622 feet 9632-9658 feet 9662-9672 feet 9678-9688 9692-9710 feet 9726-9743 feet 9755-9770 feet True vertical depth: 8773-8792 feet 8876-8896 feet 8901-8931 feet 8940-8966 feet 8970-8980 feet 8985-8995 8999-9017 feet 9032-9049 feet 9061-9075 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): • ?), ' Treatment descriptions including volumes used and final pressure: 1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 7240 200 594 Subsequent to operation: 5565 75 812 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP 0 SPLUG 0 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: 315-656 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature .11/4401.1 6147 --- 1 Phone +1 9075644424 Date 1/13/16 Form 10-404 Revised 5/2015 31 1 1 c A 7,11(/ _ RBDMS')J N 1 5 2016 Submit Original Only • • m Q,o 0 0 0 0 0 0 0 0 O O O � co co cv coOODO c0 O Nt N N cf) 0 N 00 Is- K) c0 coI- C.) y 0 0 0 0 0 0 0 0 0 0 0 0 L 0) co I- U) v- co CD Nt c) �} M d 0 COI CO COti Is- coN- vi- ca O Is- M 0 0 c0 U) 0) CO N N N N O) Is- v- M h• CO In to N I� Is- N M CO M 0 N Is- CO 00 CO O N CO OD CO CD CV O O) 00 O CO 0 CO CD N co co I- Nt CO M M I� N CO CO N CO CO 4.4C O 00 d- M M O '— O) N N N M CO O) I- CO U) M N O N O N- O CO CO O A- N N O O) 0 0) 0) N O) 0) 0) � N Q N O O) co M O O)c0 to co U) 0co cp 0) N co of) co co OU0 N 00) 0) co CO N 0) 0) CMM W I— to O. O 00 O I 000 0 000 O 000 J J O CO0J CO0000 0) k Itk J J J = N *k 0 J J J *k c0 *k c0 �? I� *k *kcV *k *k � •� U) 00 - N- CO 0)0) N M a)a),-- co 0) N 000 c ONO M CD NOCO Oc0 M ' 0N0MNCO Cv) (0 W W � O Q U U w a ZZZZZOO � cerICLr W W W W W co co co co co Z ZZ DDDDD O (/) Z Z J J J 1— I— H H H • • Packers and SSV's Attachment PBU 13-22 SW Name Type MD TVD Depscription 13-22 PACKER 2405.2 2404.97 7" Baker ZXP Top Packer 13-22 TBG PACKER 8903.97 8234.67 4-1/2" HES TNT Perm Packer 13-22 PACKER 9117.15 8440.37 7" BOT Packer • • 00 t kgb 22 / 01 O = cE = / / \ 0 0 / m 0 7 � � w b o = 0 b & 2 k � E / � z � 0k/ a) 0 6 to % 0 k a- / Lu 700 E O aG n2sa � o a9 07 N. e 7 o 0 7 | 3 2 H . 0 LUE2 £ I & -8 k < -lkw mQ " E < 20- c 0 LE _1 0 w e 0 > E@ 33 ' w ¢ E $ ƒ ƒ 3 _12 / >, a \ / / / R � E \ 000 0w mW Luz ,S) e $ m ceR 7 g2 fR = 2u � e < Rte / ¢ 3 � � � 2 � q � q / / 22 � CO a_ c f 0 b k - O z : E 2 r �o � 2 _1 2O - q < � ILce >, a) 0. _lc > / b2 � / 6. (I) _ 33 W>1 -J Ts Lu 1.- _1 4- u O D & 0 !kk � bO � � / � 7 � / g � \ Q p Q - e w q ® n k / Z / CO % _/ w ? � / tE " _k n *. DI' c CC 0 \ / 0- f2 .gE 0 \ $ ƒ / ct �� �gea. eR22wz ƒ 92 � A $ ww w2 �_ g = Lo3 ƒ 2 \ tea « II2a � � m £ 2 % � $ d -' / 0 W _j.jWW0ZI �� k co k � kc R o - m w w O Ix Q u_ ! ; a. al c 5 2 c - w \ Ln m in - >- � / \ � o I- / V- I' d ( � � q >_ R 2 2 d 0 « TREE= CNV • WH_LFEAD= GRAY alryNOTES:112$READINGS AVERAGE 126 ppm ACTUATOR= BAKER C 13-22 WHEN ON ML WELL REQUIRES A SSSV WHEN ON AIL 4-1/2 &5-1/2"CHROME 11PPLES"' BF.ELEV= ? 1 KOP= 3000' Max Angie= 32°@ 6500' Daunt MD= 9574' ' 2023233 7'' 45-1/2"5 112"FXES4-1X2NP"XO,D=3(9-CFR),D.813="4.562" Gitlin TVD= 8800'SS 5-1/2"TBG,17#,L-80 TCI, H 233T r------N .0232 bpf,D=4.892" 2392' 9-5/8"X 7"BKR LIP w/BTC LNR HGR D=6.320" 13-3/8'CSG,72#,L-80,0=12.347" H 2520' , 1, 1 / ►1 1/ ' ��4 8865 4-1/2"HESP( X N9-CtsD, =3.813' Minimum ID = 3.726" @ 9006' 14 . 4-1/2" OTIS XN NIPPLE 14 ��� 8891• 7"X 4-1/2"HES TNT PKR,D=3.856" 4 L 1 ;1 8933' _14-1/2"FES X l'43(9-CR),D=3.813" ! / 11 9006' _14-1/2"HES XN NE(9-Cts,D=3.725" 4-1/2'TBG, 12.6#,L-80 TCI, ---1, 9019' 1 0152 bpf,D=3.958" • 9019' _14-1/2"WLEG,D=3.958' VfNE 9078' 7"X 4-1/2"L-80 PORTS)SUB XO 7"SCAB LNR 26#,L-80 BTCM, H 9078' 1111 '111 —1 .0383 bpf,D=6,276' 1. y 9098' —15-1/2-BOT PBR ASSY / N 11 119100' —I4-1/2"M ESHOE,D=3.958" I1.1 -RN ►� 9117' —19-5/8"X 5-1/2"BOT 3-H PKR 5-1/2"TBG-PC,17#,L-80,.0232 bpf,D=4.892" H 9129' 9129' H5-112"X 4-1/2'XO,D=3.958" TOP OF 4-1/2"TBG-PC -1 9129' TOP OF 7"LNR H 9155' t"--1111 9178' —{9-518"X 7"LNR HGR,D=??? 9191' H4-1/2"OTIS XNNW,D=3.725" 4-1/2"TBG-PC, 12.6#,L-80,.0152 bpf,D=3.958" H 9202' 9201' —4-1/2-BOT SHEAROIJT SUB 9-5/8"CSG,47#,L-80,D=8.681" —1 8455' ` 9202' H4-12"WLEG,D=3.958' L 9182' H ELMD TT LOGGED 06/15/82 PERFORATION SUMAARY REF LOG:BI-CS ON 06/07/82 ' ANGLE AT TOP PERF:13°@ 9460' Note:Refer to Production DB for historical pert data 9623' —3"BKR BP(12/25/15) SIZE SPF INTERVAL Opn/Sgz DATE ' 3-3/8" 4 9460-9480 0 09/16/91 3-318" 4 9566-9586 0 11107/82 9688' H LNR RESTRICTION,D=4.20"(07/24/07) 3-3/8" 4 9592-9622 0 11/07/82 I 3-3/T 4 9632-9658 C 11/07/82 9707' --{L1 2 RESTRICTION,D=4.98"(07/24/07) I 3-3/8' 4 9662-9672 C 11/07/82 ' 3-3/8" 4 9678-9688 C 11/07/82 3 318" 4 9692-9710 C 11ro7/82 UNKNOWN FISit COMPOSITE PLUG PEDES 3-3/8" 4 9726-9743 C 11/07/82 3-318" 4 9755-9770 C 09/16/91 (1226109) PBTU 9924' 9897' —FISH-DA 27'X 3-1/2"PERF GUN W/CCL 1111111111111111• &DECBJTRALIZERS;LOST 06/12/82 r LNR,29#,L-80,.0371 bpf,D=6.184" 9967' ' 11111111111111114 11111111111111111 TD H 9975• 1.� 1.� DATE REV BY COMMENTS DATE REV BY COM ENTS PRUDHOE BAY UNIT 06/12/82 ORIGINAL COMPLETION 01/06/15 MGB/JWD SET BP(12/25/15) WE L: 13-22 12/28/09 Dib IWJO PERMIT No:'1820770 12/30/09 TLH DRG 110 CORRECTIONS API Pb: 50-029-20749-00 09/09/10 DBIJIVD DRUG DRAFT CORRECTIONS SEC 14,T10N,R14E,2405'FSL&81'FE. 02(09/11 NB/JIVD ADDED SSSV SAFETY NOTE 01/16/12 TMN/JWD ADDED I-12S SAFETY NOTE BP Exploration(Alaska) r • 0 r � 0cu � � v C CO U Y .V J N ❑ V x co Q CO . ❑ N v 0 o ¢ O ~Z a) C w9w m F- T OWOa 4° r- uo@ > C o Q a.. o O D W y rq +, to T Q < -� a C7 _ " a O i1/1 a.+ to H ~~ Lo d V O o d G) N a�.� C C co C~ C W Z Z ❑ ❑ ,- -6 - Q 4J N ON 0Z Q N e- N Q Z g ❑ OS -0 E O T z > t L 0 f-- ❑ ❑ ❑ ❑ ❑ f04-,o a) E -C a W J J J J -I -I crYp O O } w w w w w w oA C F. F- LL LL LL LL LL LL N 41 E -O 'n C a J J J J J J , 0 C a1 L. F- a a a a Q a O Z c. a Z Z Z Z Z Z .- 4" u m ❑ N .i K LL LL LL 1J- 11 LL ( 4Li N - 0 E C ° c o ai v w o n o v i' a eel `4 a it ra O < v _c ) > c ,0 ce o > sfd K W J lY J LL J J J U F U a -J 0 d w UIti .a � 0 U) W al8 °° w : � J 'D W c. 11 Haat 0-; 1 to ._. O � . c z !o sro ,s r. W O i i cd COC. > a E J E E E E z a0 c. � u2 2222 -..,4-1p12-,119 ,Q Illo >- >- >- >- >- aL�o a a a a a m N m m m m w w w w w ..,. E O O O O O w = . x x x s s ❑ ❑ ❑ ❑ ❑ p v u D D D R = m C v1 CYCCCLCLW to T X N C _ O u) U) N Cr U • 'Cr M 0 O 1[ O MN A% /oc,449 R4 d{/ ter. 0 Q O O N O f6 ill )��F t0 m 00 0 z U E Z (n G) l U U U ❑U c m ea rev o 0 0 0 cD o 0 0 o O o 4^ 4.1 N O N O N O C to co V •d" O 00 i in u7 (0 to r T N N N O O O O M �N N N N N N N L7. o) o) o) rn o) O 0 0 N N N N N N dLn O O O O O O _0 0 0 0 0 0 •LIn in in Ln N � �, 3=� Ca Cin _ tiZ V d7 04 L Q1 EU f0 c:nE v/CLDyamei 445, $ ce a. 8 a CG Rl M O O N N N }' v 3 co a- o +' v d Q NX (7 ,- o J E z L4!45 y a a ,ffillaialial7"111111111111.11MMiali LOF Th. \�����j,�s� THE STATE Alaska Oil and Gas 1-,— ofA ®�` Conservation Commission z 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ofALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Irwin Chou s0 Production Engineer c� 07 BP Exploration(Alaska), Inc. ! I P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-22 Sundry Number: 315-656 Dear Mr. Chou: 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, 1071.47,4Cathy '. Foerster Chair DATED this day of October, 2015 Encl. )c- nrrRBDMS 9 6 7n15 STATE OF ALASKA 0 •ALASKA OIL AND GAS CONSERVATION COMM N APPLICATION FOR SUNDRY APPRO AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0. Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program Ni"0 S' Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other SC /!CX. pl v y 1/71— 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 182-077 3_ Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519 66126. API Number: 50-029-20749-00-00• Stratigraphic 0 Service 0. 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 Nom PBU 13-22 RECE Y9 9. Property Designation(Lease Number): 10. Field/Pools: 0T 1 Vit;_/s ADL 0028315• PRUDHOE BAY,PRUDHOE OIL. 11. PRESENT WELL CONDITION SUMMARY �' Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk( e 9975 • 9276 . 9924 9226 9208/9897 Casing Length Size MD ND Burst Collapse Structural Conductor 81 20"91.5#H-40 40-120 40-120 1490 470 Surface 2488 13-3/8"72#L-80 39-2528 39-2527 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 - 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 / Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG I' ,,qty Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 Id SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chou,Irwin Email Irwin.Chou@bp.com Printed Name Chou,Irwin Title Production Engineer Signature --- '. Phone +1 907 564 5538 Date 10/ - / f COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 7D6 - _s Le Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Spacing Exception Required? Yes❑ No 11 Subsequent Form Required: `(9 -464- APPROVED BYTHE Approved by: ia (� COMMISSIONER COMMISSION Date:`/j' TL /0/2y/dc ORIGINAL RBOM Or.T 2 6 2015 ./ Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • CI) 0.0 0 0 0 0 0 0 0 0 0 0 0 a, N- (0Oor- 0Nx- Coo000 — (ON- o o c.1ONO N O O N- N- O CO N- CO N Vy is 00) C) NOCcYC) CO () ,7C) m• r Nr CO CO CO c0 N- N CO ti CO O N- CY) O O CO O 0) CO N N N N O N- C7 N- CO L O O N O N- N- V N Ch C7 Cr) cr O N N- CO CO CO 0) N CO CO CO LO CT) H 00) CO00 - COOCO NtN N- N CO CO N CO CO i+ C) OCO M Ch v 0 •- 0) N NNMCo0) - N- COL0C O � Co 0 c•) c) 0 — N NCOO) 0) 0) 0) N0) 0) 0) CI Q co �I C) 0OcoCMCMOMON N co N 0) O) N 0) 0) C O a 0 J oco 0 ' co ocoo0 � JJOOODJ000ODJaJiJ kN (/) -J kco *ktto .� N O N N 0) CO r V O _0-0 = = - ( N - O d O .c co CO 00C0) NOpN ' NCNDCOC�) C CO M 0 CO N M C'r) CO Cr) N J N CO r- CO O N CO W W Q Q Cri O C WW W co U o D u_ cew cerx � Z Z Z Z Z zceW W W W W ODF"" 1— ZZZDDnjj UV) ZZJJJHI— HI— I— • • d m CON- COcYN- N- MM t N to CO Cn r- CO O) NOMOCAOCOCoLC) , O) O) CO N- 0) • N C] N. COco0) 0) 0) 000 CO CO CO CO CO 0) 0) 0) a 0 Nt 1' N- N. vi. CO t- CO C 15. N- 0 1' N O M CO aNCOCAO0NO a m N- O1" CO0) MCD W 0 NCOC)) CAOOCAOO > O COao ao CO CO O CO C)) v) 0 ceUi W 0 0 W Z co W gg ° o w Y 0 O O O �C Y t O CO N CO N CO O CO O J J J ¢ ¢ In W V CL CO CON ON CO N— ¢ ¢ ¢ w 0_ 0_ Z V 0 CO CO O O N- N- N _0 0_ 0_ J W •W C7 0 0) 0) 0) 0) 0) 0) 0) 0) 0) Z Z O J J J p J '5 ¢ ¢ ¢ = p p d W d 0 0 0 W w Z p Z go w w w 0_ F H ¢ J ¢ Qr 2 2 2 O m m co co co Q N 0. 0 CO N CV N CO N CO LO O .I m• CR.10A c (o- c°'ON � 0) 0) 0) 0) 0) 0) 0) 0) 0) 0 '5 ca O a m Y 0 Orn `t 2220 u) ~n tan ti can fi C, O C) C Zawwwwwwwa Q a a a a a 0. a ¢ 0. O m a CU R x— N N N N N N N 0 0 0) Co CO CO CO Co CO CO 0) 0 C CD 0) 01 0) 0) 0) 0) O O W LL0 IX Z CO N- N N- N N N. N CO d W J 0 W W O co O Z J 0 W W W W O m W J J J 0 0_ ¢ ¢ acn � cOna � 0 E eo Z N N N N N N CV N N 3 N N N N N N N N (N U. 0- cn 0 IL N �, tL Cr) M CO CI C'1 ) M M c1) Cr) m 0_ a s 0 a a w o. ¢ ¢ mmu_ . cncno_ • Packers and SSV's Attachment ADL0028315 SW Name Type MD TVD Depscription 13-22 PACKER 2405.2 2404.97 7" Baker ZXP Top Packer 13-22 TBG PACKER 8903.97 8234.67 4-1/2" HES TNT Perm Packer 13-22 TBG PACKER 9117.15 8440.37 7" BOT Packer • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: 13-22 Well Type: Water Injection Well API Number: 50-029-20749-00 Well Activity Conventional 4 Classification: Activity Description: Set Hex Plug Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bond: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory None requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Irwin Chou Contact numbers: (907) 564-5538 (907) 632-3992 Well Intervention Engineer: Ryan Thompson Contact numbers: (907) 564-4535 (907)301-1240 Lead Engineer: Bernhard Stechauner Contact numbers: (9071 564-4594 (907)360-7485 Date Created: October 5, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate Date (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Pressure (psi) Cut(%) (Mscf/Day) 9/16/2015 4,952 373 Current Status: Operable Flowing Inclination>70°at Depth(ft) N/A Recent H2S (date,ppm) NA 0 ppm Maximum Deviation(Angle and 32° 6,500' MD Depth) Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 4° 3,700' MD Reservoir pressure(date, 1/16/2010 3,343 psi Minimum ID and Depth 3.725"Q 9006' MD psig) Reservoir Temp,F 154° F Shut-in Wellhead Pressure 500 psi Known mech. integrity None problems(specifics) Last downhole operation (date, 1/1/2010 Pull B&R and RHC from XN nipple post RWO operation) Most recent TD tag(date,depth, 1/1/2010 9,683' MD 3.65"CENT,TEL,S-BAILER toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, Based on an IPROF in 2006,the majority of 13-22's injection is entering the 43P. All of the surrounding background information, wells with 43P production are LTSI.The only operable well in the pattern is 13-34, which produces from etc: the 45-46P. The plan is to isolate the lower Z4 perfs in 13-22 to force injection higher and support 13-34. . Note: An opportunistic IPROF will be run on SL to see if injection conformance has changed within the last 10 years. • • • Well Intervention Details Suspected Well Problem: 13-22 Injection not supporting 13-34. Specific Intervention or Well Objectives: 1 Drift&caliper for HEX plug 2 !PROF 3 Set Hex Plug Key risks,critical issues: Mitigation plan: 1 There is only-10ft of stand-off between perfs where plug will be set. 2 3 Summary Step# Service Line Activity 1 S Perform caliper log. Drift for Hex. Log IPROF. 2 EP Set Hex Plug. Do not schedule until approved by PE. 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 S Perform caliper log from TD to surface. Drift with 363-700 HEX drift from WLB (-3.66" OD x 13')with a 10' x 3.625"joint above HEX drift. Log (PROF per logging sheet. Set 363-700 Hex Plug at 9626' MD (review 3D caliper data to set HEX in best pipe between depths of 2 EP 9622' MD and 9632' MD if 9626' is bad pipe. Staying-2 ft from any collars and out of perf zones). HEX BHA to include N2 setting tool from Interwell. Place schematic of HEX plug in well pictures folder, include pulling tool dimensions on the picture. Do not schedule until approved by PE. 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: Post job POP instructions: Turn over to OPS to POI. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • • . — TREE• OW SAFETY NOTES:MS LEADS=AVERAGE 125 ppm WELLI-EA0• GRAY 64WHIN 0 I 1111.WELL REQUIRES A USW WHEN ON B ELEV ACTUATOR• BAKER C 13-22 Y I-4-1rr a 11-1/2-CHROME RIM.EIP'•" K • * EIF ELEV• 7 r I Koe. X00' 51C4 ANA• 33'0 war Down MD. 61574' • I 2023' 1,._15-1f7 HES X NP 011-CFS,10•4 5r2- I °Own TVO• sear SS ./' 2337' 5-1/7 4-1/7 X0,0.3 613' 5-1/7 THG,171,L-80 ma, H 2337" 0232 tag,0•4 ear 2392' 1 9-Ur x r UR LTP w ierc uot 4 ,s mut 0.8 320- 131-71—ier csg:i,IZO,LAW,u•iz s4r H 2620 j 1 4 .1 '0 k ,1 - ••,• 0 II 81311' 41/7 HES X NP1s-cFq, .11 , Minimum 0 ii 3.725"a WOG' • •4 ,1 4-1/2"0718 XN NIPPLE • •• . m,. .• MI' 7'X 4-1 a-HES TNT PKR,0•3 We iep , I.P, • mg., •114 9933' L.14-1/2'HES X10'(5-CRI,0•3 613' 1 V 0 ••• .1 .I • I DM' 1_141/7 HES XN la,(9-og,0•3 725' 4-irr Tack 12 et Lao Ta. H 001ir 44. 41 • ,4 0152 bp(,0-3 056- 1/. : limy 4-1/7 ink.E0,0•3 Mr 4 .• t•• 90711' j_jr x 4-i7 L-OC P0FifED sus XO I 7-SA :P4R NM I-Afl EiTriA -I 0070' •••4 •• 101,,I 003 bpf,0•6 276- 01. ., ,• el WYSS H5-1/7"ROT R3R A WY I •I ,0 .$• 0,...1 ••i 11004-1/2MULE 3/-0E,0-3.•50" • ••• .4• ved 110=41 lia4 9117' 9-54 X 5-1/7 50T 341 MGR 1 5-1r:THG-PC,1711,L-60, 023bp1,0•4 Orr 912W 9129' so fr X 4-Irr xo,0•3 95r ITce oF 4-11r TB0-PC H *1 a' I imp oF r LuR •155' 9175' is-Sar x r 04R HGR,0•777 I f intv 1—(4-Ia.ars XN me,0•3 ris" 1 4-1/7 TSG-PC,1201.L-61, 0152 bpi.0-3 456" 1120W 9201' H4-1/7 SOT srEA Rota sus I ! -.II 9-Sr 080,471.L-l0,o•9 ear EMnill 920r 4-1/7 VAEG,0.3 566' I 9182' H amp Tr Loomo con sez j FERFORAT1ON SLAIMARY REF LOO BRCS ON 06107E2 AME Al TOP FERF 13'0 WU i.v 61 P4:40.Rotor to%diction CS for notoned god Oki i 4- k( /c v / SIZE SFC INTERVAL Oon/Eciz DATE 5- 3-34r. 4 ' 94X-9460 0 0;61660 *-- ,' _ -$_ I- ----- 3-343' 4 9556-9566 0 110742 ._ ,f sear Ht./4Ft RESTR0T0N,0•420'(07a407) I 3-34' 4 9682-91122 0 1147652 I 3-316- 4 9832-9150 0 1147/62 i 9707" Hu.: $1 TON.0•4 011'(07/24/07) j 3-34' 4 9/632-0572 0 11/07/62 334' 4 0671566M 0 1107/62 I • 3-34' 4 91102-9710 0 11/07112 UNK/40W NI-/on ccorcaire PLuo Pecos 3-14' 4 9735-9743 0 11/07/S2 3-346" 4 9755-9770 0 06/16/01 ,. (12/2600) siT110 -{ 9024' } 'AI { seem I—FISH-DA 7 7'x 3-1 rr PFRF C1.Pf Vata. ••• •0110 8 DECENTRA la ERS,LOST 08/1 2152 1041011110.4 7F7.77,6t,?it,L-90 0371 bpf,10•I leor H leer •••••••• 1111111110.04 411101/11•411 •••••1000 10 9970' teAtaasAa DAIE Re,/BY COPAMENT3 - DATE .Fe/BY commarrs , FP3.0r0E BAY UHT ovum ORIGINAL COW PI trioN Wal. 1322 I moot' ots *istfiapeRmr No learno -. 12/3000 TU-i CRL 0 HO CORRECMNS 7 A P Ni7 50-020.20749-(37 00•31710 i0.10 CRLo IPAFT coRRECTONS - SEC 14,T1 F04E,24os FSI.881 Ra. 02W11•1.031.18:1 A CCED SSSV SA:EY NOTE-.. -.. 'Diner 7 TWIIJOAD ACCII)K2'S SAFETT NOTE ..- OP Boioration(Alaska) .. .. . . ...... .. .. , _ .. ..., ... _, ._. . .......... ............. .,. . . • • Injection Profile Log Ver 3.0210/02/13 LHD Well: 13-22 Prop.Code: CC or AFE: APBINJEC API#: 50-029-20749-00 Name: Irwin Chou Contact numbers: (907)564-5538 Proc.Dist. Date: 10/5/2015 Contact numbers: (907)632-3992 Town: Contact numbers: APE Well File Objectives(In order of importance): Slope: W/L(3) Log IPROF on memory to obtain injection splits. FE Loqqinq Notes: 1)RIH with: GR/CCL/SPINNER/ILS/TEMP/PRESS If Gradiomanometer is needed,give inclination of logging interval 0.0° 2)Other Info: . F IPROF Flowing Up/Down 40 9300'-TD Well on injection (PWI) Flowing Up/Down 80 9300' -TD Well on injection (PWI) Flowing Up/Down 120 9300' -TD Well on injection (PWI) Flowing Up/Down 160 9300' -TD Well on injection (PWI) Shut In Up/Down 50 9300' -TD Shut in Well. Perform warm back 'asses @ 1 hr 3hr&5 hr intervals. LOG PRESENTATIONS 1.Job Comments—operating steps in sequence,flow rates for logging passes and basic field interpretation including production and injection splits. 2. Flowing Overlay—Spinner,temperature and pressure data from the 60 fpm up passes. Presented on a 5"/100ft. Note flow rates for flowing pass in log header. 3.Flowing UP Pass Overlay—Spinner,temperature and pressure for 40 fpm,60 fpm,and 80 fpm passes. 4. Flowing UP/Down Pass Overlay—Spinner,temperature and pressure for 60 fpm passes. 5. Production/Injection Overlay—Spinner,temperature and pressure for 60 fpm up passes. 6. Baseline Injection/Borax Overlay 7.GHOST Log • • hp ,;� �� twrr►,to9 Techlog Scat.:;PresetS Well: 13-22 Os*J. $ 41 x 4at1a'INE W VD Dow 14024$44*MN cows USA KoheteKKKon KO 0 wr aawa KKK loyeibee*n YKK Omit feta OAKKOKS..141141116234 Sima Vox Waft * TOMO aa'xa torPoor.h41 Of* *Mot* TWO 01WOW gyro ..:,. ,„¢ 1�IOa 14%) PE Notes 0 OT X CAL.!r.. + z ,; 6,� 1 ii" .` # F : 2 dmf Off SW P0* e•.i,t is + r ♦ 3. rll n "WOO ± y rx, 5 41 raw 4 f0. 5. Apt,„4„,, Fr ♦ , ptrct ,1,,, I e r''',1,-,1";". a ,''f''„0,,, J"F ( f �r, a F�� . . a a''' yf a44404.,jy+. 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'7__ 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: D Other BY; Project Proofing .. BY: BEVERLY ROBIN VINCENT SHERYL MARIA Wl~ DATE'.O'/CC ,B, Scanning Preparation ,..__~ x 30 = + _ _ = Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: / PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: //~ YES BY: BEVERL'~VINCENT SHERYL MARIA WINDY DATE:) -/~,~"~l~/S/ NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO ReScanned (individual page [special af~e~ti~] ~catming complet, ed) RESCANNED BY; BEVERLY ROBIE VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: ISl Quality Checked 12110/02Rev3NOTScanned.wp~ STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other Q BRIGHTWATER Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ TREATMENT Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ " 182 -0770 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑r 6. API Number: Anchorage, AK 99519 -6612 a 50- 029 - 20749 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028315 :� PBU 13 -22 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 9975 feet Plugs (measured) No feet true vertical 9276 feet Junk (measured) UNK, 989 feet Effective Depth measured 9924 feet Packer (measured) 8891 9117 feet true vertical 9226 feet (true vertical) 8222 8440 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" SURFACE -79 SURFACE -79 1490 470 Surface 2520' 13 -3/8" 72# L -80 SURFACE - 2520 SURFACE - 2520 4930 2670 Intermediate 9455' 9 -5/8" 47# L -80 SURFACE - 9455 SURFACE - 8768 6870 4760 Production Liner 812' 7" 29# L -80 9155 - 9967 8477 - 9268 8160 7020 Scab Liner 6708' 7# 26# L -80 2392 - 9100 2392 - 8424 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# X 4 -1/2" 12.6# L -80 SURFACE - 9109 SURFACE - 8432 5 -1/2" 17 #X4 -1/2" 12.6# L -80 9083 -9202 8407 -8522 Packers and SSSV (type, measured and true vertical depth) 7" X 4 -1/2" HES TNT PKR 8891 8222 9 -5/8" X 5 -1/2" BOT 3 -H PKR 8440 12. Stimulation or cement squeeze summary: Intervals treated (measured): A�D NGV 17 LUl� � 2010 Treatment descriptions including volumes used and final pressure: M: "!j 63 C0173, UP C t�'t,'rSS100 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 11067 744 Subsequent to operation: 8063 544 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory El Development ❑ Service !❑� Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil El Gas WDSPL LJ GSTOR ❑ WINJ ❑ -WAGQ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na a Jo Lastufk Title Data Manager Signat' re I/ ^ —_ Phone 564 -4091 Date 11/16/2010 Z0� �, Form 10 -404 Revised 10/2010 RBDNAS NOV 16 7Z 11.17 /p Submit Original Only i<l 1110 1 13 -22 182 -077 PERF ATTACHMENT S 2 2ame O eratio_n 71 P erf O peration Code _l Meas Depth To p Meas De Bas T D To p Tvd Depth Base - - - -p PER 9,566. 9,586. 8,876.04 8,896.56 13 -22 - -+ 1 1/7182 PER 9 , 69 2 9,710 8,999.081 9 ,016.67 13 - -2_2_ 11/7/82 PER - 9,678. 9,688. 8,985.4 8,9 95.17 13 -22 � 11/7/82 PER 9,726. 9,74 3.1 9,032.31 9,04 13 -22 11/7/82 PER - - 9,6 9 658. 8,940.47 8,965.86 13 - 2 2 11/7/82 PE 9,592 9,622. 8,901.41 ' 8 9 30.7 - — -- 13 -2 2 11/7/82 PER 9,662.1 - -- 9,6 8,969.7 8,979.54 1 -22 9/1 APF 9 ,460. 9,480. - 8,7 - 72 - .74: i 8 13 -22 � 12/ - - -- -_- - -- - 9,189 _ ___ __ -_ 9,199. - 8,509 _ - -- - 13-22 9/16/91 A 9,755 9 9, 9,075 33 _ 8,519.48 13 -22 1214/09 BPP - - 9,1 - -- - - 9,199 8,509.81 8,519.48 - -- • 13 -22 1 2/5/09 BPS 9, 145. 9 8,467.28 8,468. 13 -22 - -- - -- - 12/26/091 BPP - — 9,145.' 9,146., 8,467.28 8,4 -- - - -- - - - -- - - -- - - - - -- - - - - - -- - - -- - AB ABANDO rt `PER P ERF APF ADD PERF IRPF REPERF BP _ _ BRIDGE PLUG PULLED --- r SL SLOTTED LINER BPS BRIDGE PLUG SET ISPR ! SAND PLUG RE MOV E D F FILL CLEAN OU_ _ SPS ,S PLUG S ETS _ I MECHANI IS SQF SQUEEZE FAILED M R 4 IS OLATED REM_ OVED SQZ ' SQ L MIS MECHANICAL ISOLATED , STC STRADDLE PACK, CLOSED - - -- -- +- MLK ME LEAK S _ STRADDLE PACK, O PEN OH PEN HOLE • 13 -22 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/27/2010 T /1 /0= 500/40/200 Temp =inj Pump Brightwater Chemicals (Reservoir Sweep Mod) l Start Pumping Brightwater Treatment down tubing while on water injection @ 8000 bwpd 6 Pumped 319gal. EC9660A (Low -Temp Surfactant) at an average of 63 gph for 5 hrs. Pumped a total of 319 gal. since start of treatment. Pumped 895 gal. EC9378A ( Polymer) at an average of 200 gph for 4.5 hrs. Pumped a total of 895 gal. since start of treatment. * *WSR continues on 10- 28 -10 ** 1 10/28/2010; ** WSR Continued from 10 -27 -10 ** Pump Brightwater Treatment (Reservoir sweep t mod) !Pumping Brightwater chemicals down tubing while on water injection @ 8000 bwpd I Pumped 1261 gal. EC9660A (Low -Temp Surfactant) at an average of 53 gph for 24 hrs. Pumped a total of 1580 gal. since start of treatment. Pumped 5000 gal. EC9378A ( Polymer ) at an average of 208 gph for 24 hrs. Pumped a total of 5895 gal. since start of treatment. ** WSR Continues on 10 -29 -10 ** a 10/29/2010* WSR Continued from 10 -28 -10 **Pump Brightwater Treatment (Reservoirs ee mod) Pumping Brightwater chemicals down tubing while on water injection @ 8000 bwpd Pumped 1283 gal. EC9660A (Low -Temp Surfactant) at an average of 53 gph for 24 hrs. Pumped a total of 2863 gal. since start of treatment. Pumped 5057 gal. EC9378A ( Polymer) at an average of 210 gph for 24 hrs. E Pumped a total of 10952 gal. since start of treatment. ** WSR Continues on 10 -30 -10 ** ` 10/30/2010`* WSR Continued from 10 -29 -10 ** Pump Brightwater Treatment (Reservoir sweep j mod) j Pumping Brightwater chemicals down tubing while on water injection @ 8000 bwpd 1 Pumped 1191 gal. EC9660A (Low -Temp Surfactant) at an average of 55 gph for 21.51 1 hrs. Pumped a total of 4054 gal. during this treatment. ' Pumped 3883 gal. EC9378A ( Polymer ) at an average of 205 gph for 19 hrs. !Pumped a total of 14835 gal. during this treatment =RDMO ** *Job Complete * ** � i FLUIDS PUMPED GALS 4054 EC9660A (LOW -TEMP SURFACTANT) 14835 EC9378A (POLYMER) 18889 TOTAL TREE: CMJ WELLHEAD = GRAY 13-22 FRY NOTES: ""`4 -1/2" & 5 -1/2" ACTUATOR= BAKERC tCHROMENIPPLES KB. ELEV = 84' BF. ELEV = ? KOP = 3000' Max Angle = 32° @ 6500' Datum MD = 9574' 2023' 5 -1/2" HES X NIP (9 -CR), ID = 4.562" Datum TVD = 8800' SS 2337' 5 -112" X 4 -1/2" XO, ID = 3.813" 5 -1/2" TBG, 17 #, L -80 TCII, 2337' .0232 bpf, ID = 4.892" 2392' 9 -5/8" X 7" BKR LTP w /BTC LNR HGR, ID = 6.320" 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 2520' 8865 4 -1/2" HES X NIP (9 -CR), ID = 3.813" Minimum ID = 3.725" @ 9006' 8891' 4-1/2" OTIS XN NIPPLE 7" X 4 -1/2" HES TNT PKR, ID = 3.856" 8933' 4 -1/2" HES X NIP (9 -CR), ID = 3.813" 9006 4-1/2" HES XN NIP (9 -CR), ID = 3.725" 4 -1/2" TBG, 12.6 #, L -80 TCII, 9019' .0152 bpf, ID = 3.958" 9019 4 -1/2" WLEG, ID = 3.958" 9078' 7" X 4 -1i2" L -80 PORTED SUB XO 1 7" SCAB LNR, 26 #, L -80 BTCM, 9078' . 0383 bpf, ID = 6.276" 9098' 5 -112" BOT PBR ASSY 9100' 4 -1/2" MULE SHOE, ID = 3.958" 9117' 9 -5/8" X 5 -1/2" BOT 3 -H PKR I 5-1/2" TBG -PC, 17 #, L-80_0232 bpf, ID = 4.892" 9129 9129' TOP OF 4-1/2" TBG -PC 9129 i TOP OF 7" LNR 9155' 9178 9191 4 -1 /2" OTIS XN NIP, ID = 3.725" 4 -1/2" TBG -PC, 12.6 #, L-80_0152 bpf, ID = 3.958" 9202' 9201' 4 -1/2" BOT SHEAROUT SUB 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 9455' 9202' 4 -1/2" WLEG, ID = 3.958" 9182' ELMD TT LOGGED 06/15/82 PERFORATION SUMMARY REF LOG: BHCS ON 06/07/82 ANGLE AT TOP PERF: 13' @ 9460' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 9460 -9480 O 09/16/91 3 -3/8" 4 9566 -9586 O 11/07/82 L 9688' 1 /07/82 9688' LNR RESTRICTION, ID = 4.20" (07/24/07) 3 -3/8" 4 9592 -9622 O 11/07/82 3 -3/8" 4 9632 -9658 O 11/07/82 9707' LNR RESTRICTION, ID = 4.98" (07124/07) 3 -3/8" 4 9662 -9672 O 11/07/82 3 -3/8" 4 9678 -9688 O 11/07/82 3 -3/8" 4 9692 -9710 O 11/07/82 UNKNOWN FISH: COMPOSITE PLUG PIECES 3 -3/8" 4 9726 -9743 O 11/07/82 (12/26/09) 3 -3/8" 4 9755 -9770 O 09/16/91 PBTD 9924' 9897' FISH - DA 27'X 3 -1/2" PERF GUN W /CCL & DECENTRALIZERS; LOST 06/12/82 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" 9967' TD 9975' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/12/82 ORIGINAL COMPLETION WELL: 13 -22 12/28109 D16 RWO PERMIT No: ° 1820770 12/30/09 TLH DRLG HO CORRECTIONS API No: 50- 029- 20749 -00 09/09/10 DB /JMD DRLG DRAFT CORRECTIONS SEC 14, T1 ON, R1 4E, 2405' FSL & 81' FEL BP Exploration (Alaska) MEMORANDUM To: Jim Regg ~~~ 4 ~ll~ ~l~ P.LSupervisor "~_l FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 07, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-22 PRUDHOE BAY UNIT 13-22 Src: Inspector rTnN_rnNTimFNTi e i . Reviewed By: P.I. Suprv,~~_" Comm Well Name: PRUDHOE BAY UNIT 13-22 mitJCr100208164805 Insp Num: Rel Insp Num: MITOP000002958 API Well Number: 50-029-20749-00-00 Permit Number: 182-077-0 Inspector Name: John Crisp Inspection Date: 2/5/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13'22 Type Inj. ~'~' " TVD szzz ' IA 27o z2oo - zlso zlao P.T.D 1820770 TypeTest SPT Test psi 2055 i QA 470 660 660 640 Interval ~IT'~- ~ p/F P / Tubing 520 540 540 540 Notes: Wednesday, April 07, 2010 Page 1 of 1 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI.ON REPORT OF SUNDRY WELL OPERATIONS ~Ec~~v~D J,AN 2 0 2Q10 1. Operations Performed: ~~~~ a - ~ ~ ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended ~~~~ ® Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: . Permit To Drill Number: BP Exploration (Alaska) Inc.. ^ Development ^ Exploratory 182-077 3. Address: ®Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20749-00-00 7. Property Designation: 8. Well Name and Number: ADL 028315 PBU 13-22 9. Field /Pool(s) Prudhoe Bay Fietd / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured ~ 9975' feet true vertical ~ 9276' feet Plugs (measured) None Effective depth: measured 9924' feet Junk (measured) Yes (See Diagram) true vertical 9226' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 7g' 20" 79' 79' 1490 470 Surface 2520' 13-3/8" 2520' 2520' 4930 2670 Intermediate 9455' 9-5/8" 9455' 8768' 6870 4760 Production Liner 812' 7" 9155' - 9967' 8477' - 9268' 8160 7020 Scab Liner 6708' 7" 2392' - 9100' 2392' - 8424' 7240 5410 ~~~ .~~~`~ ' ' ~ ~ 2~~~ Perforation Depth: Measured Depth: 9460 - 9770 True Vertical Depth: 8773' - 9075' Tubing (size, grade, measured and true vertical depth): 5-1/2", 17# x 4-1/2", 12.6#; L-80 5-1/2", 17# x 4-1/2", 12.6# L-80 Surface- 9109' 8432 ; 9083' - 9202' 8407' - 8522' d and true vertical de th): m r P k d SSSV t 0 ~ ' ~~ p ~ ers an ( ype, easu e ac 7 x 4-1/2" HES TNT Perm. Packer; r; • 8222 ; 8891 9-5/8" x 5-112" Baker'3-H' packer 9129' 8452' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from --9083'. Run 7" (26#, L-80) scab liner. Cement w/ 197 Bbls Class'G' (Yield 1.16). Clean out and run tubing to 9019'. 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run 4. Well Class after work: ^ Exploratory ^ Development ®Service ll O rati ns ® D il R rt f W y o e pe o a epo ® Well Schematic Diagram Well Status after work: ^ Oil ^ Gas ^ WDSPL ^ GSTOR ®WAG ^ GINJ ^ WINJ ^ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564-5683 309-335 Printed Name Terrie Hubble Title Drilling Technologist D 1 ~ Q Prepared By Name/Number: Phone 564-4628 Date Signature ~ ` ~ ~ Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009" ' ' RBDMS JAH 212010 ~ri'rr-. ~ 1. Z.,r~o ~T' Oal Only 13-22, Well History (Pre Rig Workover) Date Summary 10/8/2009 T/I/O=SSV/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (350 psi), bled to 0+ psi, unable to bleed to 0 psi, pressured back up to 350 psi. Functioned LDS, all moved freely (1 "). Single port, unable to pump through void. Unable to pressure test void above 800 psi, presure self bled back to 350 psi. Stung into body seal test port (0 psi). Pressured void to 5000 psi, lost 100 psi in 15 min, lost 0 psi in second 15 min. Elastomer seal and metal to metal seal are holding. Bled void to 0 psi. *"LDS energized elastomer body seal and metal to metal seal on bottom of hanger are holding, neck seal on hanger is leaking. These seals will provide barrier to ND and remove tree and Rig will be able to test BOP. PPPOT-IC: Stung into test port (50 psi), bled to 0 psi. Functioned LDS, all moved freely (1 "). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 12/4/2009 MIRU. PULL PRONG C~ 9166' SLM, PULL PXN BODY C«3 9170' SLM / 9189' MD. DRIFT TBG W/3.50 CENT/TEUSAMPLE BAILER. TT C~ 9179' SLM + 3' = 9182' ELM, TAG TD C«3 9812' SLM + 3' = 9815' ELM. SET 4 1/2" WFD COMPOSITE PLUG C~3 9159' SLM, 9175' MD. LRS PERFORMED MIT-T 1000# (FAILED). SET 2nd 4 1/2" WFD COMPOSITE BRIDGE PLUG C~ 9129'SLM, 9145' MD . LRS PERFORMED MIT-T 1000# (FAILED). 12/4/2009 T/I/0=0/0/0, Temp=S/I, Assist S-line w/LDL. MIT-T FAILED to 1000 psi (RWO Prep). Pressure up tubing with 4 bbls of 0° 60/40 and 28.7 bbls of 0° diesel to reach 1000 psi. MIT-T lost 400 psi 1st 15 min. and 240 psi in 2nd 15 min. for a total of 640 psi in 30 minutes. Slickline set new composite plug and pumped 2.7 bbls diesel down tbg to reach test pressure. Loss of 100 psi 1st 15 min. Loss of 50 psi 2nd 15 min. 12/5/2009 LRS PERFORMED MIT-T 2400# (PASS). NO LEAK IN TUBING. PERFORMED PDS SPINNER, PRESSURE, TEMP LDL AS PER PROGRAM (GOOD DATA). LRS PERFOMED MIT-OA 2000# (PASS). WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. 12/5/2009 Assist S-Line MIT-T PASSED to 2400 psi. Pumped 3.3 bbls diesel down Tbg to reach test pressure. Loss of 40 psi 1st 15 min. Loss of 20 psi 2nd 15 min. Bled tbg to 0 psi. Pumped 100 bbls of 0°F diesel down IA at 2700 psi at a rate of 2.7 BPM. Slowed rate to .6 BPM, pumped additional 69 bbls of diesel at 400 psi for Slickline to run log for a total of 169 bbls of diesel down IA. Pressured up OA with 2.1 bbls of diesel to reach 2000 psi. MIT-OA lost 60 psi in 1st 15 minutes and 20 psi in 2nd 15 minutes for a total of 80 psi in 30 minute test. Bled down OAP. Slickline on well upon departure. FWHP's=90/160/0. 12/9/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 0/200/150 RIG UP ELINE TO CUT 5.5" TUBING WITH 4.15" POWER CUTTER. 12/10/2009 .CUT TUBING AT 9080' WITH 4.15" POWER CUTTER. FINAL T/I/0=400/0/100 JOB COMPLETE. 12/11/2009 T/I/0=0/0/0 Temp=Sl Circ. out (RWO Prep) Pumped 3 bbl neat meth spear down TBG, followed by 937 bbls 9.9# Brine & 31 bbl Diesel Freeze Protect. Took returns up IA to well #2. Dead head 13 bbls DSL down IA for FP. Bled WHP. FWP=O/0/0 Tags Hung. SV, WV &SSV = S/I. MV, IA & OA =Open. 12/13/2009 T/I/O = 0/0/0. Set 5" Gray "K" BPV #601. 1-2' ext used. Tagged C~? 108". No problems. Pre-Doyon 16. 12/13/2009 T/IA/OA= SI/0/0 Temp=cold Remove W/H jewelry SMR needed to have gauge and needle valve removed, Pre Rig move onto well. Closed in (1) needle valve bled gauge and (2) needle valve to 0 psi. Removed gauge and needle valve installed JIC fitting with cap, removed SMR shroud left on ground. Page 1 of 1 • BP EXPLORATION Page 1 of 10 .Operations Summary Report Legal Well Name: 13-22 Common Well Name: 13-22 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code ~ NPT 12/17/2009 12:00 - 00:00 12.00 RIGD P 12/18/2009 00:00 - 16:00 16.00 RIGU P 16:00 - 19:00 3.00 WHSUR P 19:00 - 20:00 1.00 WHSUR P 20:00 - 21:30 1.50 WHSUR P 21:30 - 00:00 2.50 WHSUR P 12/19/2009 00:00 - 01:00 1.00 WHSUR P 01:00 - 02:00 1.00 WHSUR P 02:00 - 03:30 1.50 WHSUR P 03:30 - 08:00 4.50 WHSUR P Spud Date: 5/25/1982 Start: 12/14/2009 End: 12/28/2009 Rig Release: 12/28/2009 Rig Number: Phase ~ ' Description of Operations PRE RDMO FROM GNI-03. -16:35-hrs NOTIFIED AOGCC OF UPCOMING BOP TEST. 16:36-hrs BOB NOBLE WAIVED STATE'S RIGHT TO WITNESS. -23:59 hrs MOVED ONTO DS 13. PRE MOVE ONTO DS 13. -REMOVE BOOSTERS. -PJSM -RAISE DERRICK. -R/U FLOOR EQUIPMENT. -RECONFIGURE BOPE STACK. DROP ONE SET OF PIPE RAMS. -PJSM -SPOT AND SHIM THE RIG OVER WELL 13-22i. -SPOT SLOP TANK AND EQUIPMENT. -R/U LINES TO CIRCULATE WELL. -RIG ACCEPTED AT 1600-hrs. DECOMP PJSM. P/U LUBRICATOR IN PIPE SHED, BRING UP TO FLOOR. -PULL TREE CAP AND DRIFT TREE.. -FILL TREE WITH DIESEL TO TEST LUBRICATOR. DECOMP WAIT ON DSM TO CHANGE OUT -CLEAN UP LEAK OF 9.8 PPG BRINE FROM HOSE GASKET FAILURE. DECOMP R/U LUBRICATOR TO TREE. -TEST LUBRICATOR TO 500 PSI. GOOD TEST. -PULL K-PLUG. -OA = 0 PSI, TUBING = 0 PSI, IA = 0 PSI. DECOMP PJSM FOR CIRCULATING OUT DIESEL. -PRESSURE TEST ALL LINES. -REVERSE CIRCULATE 9.8-ppg BRINE, TAKING 18 BBLS TO GET RETURNS, REVERSE CIRCULATING 32 BBLS TOTAL. -SHUT DOWN AND RIG UP TO PUMP DOWN TUBING. -CIRCULATE ~ 6-bpm AND 430-psi. DECOMP CIRCULATE ~ 6-bpm AND 430-psi. -CIRCULATED A TOTAL OF 680 BBLS. -LOSSES DURING CIRCULATION WAS 102 BBLS. -SHUT DOWN AND MONITOR WELL FOR 20 MIN. WELL STATIC. DECOMP R/U LUBRICATOR AND TEST TO 500 PSI. -SET K-PLUG WITH LUBRICATOR. -CAMERON - T-BAR IN DART. DECOMP PJSM PRESSURE TEST K-PLUG AND DART FROM ABOVE TO 4000-psi FOR 10 MIN. -GOOD TEST. -ATTEMPT TO PRESSURE TEST FROM BELOW. SHUT DOWN AND CHECK CHART. RECHARGE HOSES, CHANGE OUT HOSES TO CHART RECORDER. -PRESSURE UP TO 1100-psi FROM BELOW AT 1.5 BPM AND HOLD FOR 10 min. WHILE ROLLING PUMPS. -BLEED OFF ALL PRESSURE. -PUMPED AWAY 72 BBLS TOTAL WHILE PERFORMING ROLLING TEST. DECOMP PJSM FOR N/D TREE. DISCUSSED SINGLE BARRIER DISPENSATION REQUIRMENTS WITH CAMERON, RIG rnmeu: ui uc~iu icai.vv rrvi BP EXPLORATION _ Page 2 of 10 Operations Summary Report Legal Well Name: 13-22 Common Well Name: 13-22 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task ~ Code ! NPT 12/19/2009 03:30 - 08:00 4.50 WHSUR P 08:00 - 12:00 4.00 BOPSU P 12:00 - 20:30 8.501 BOPSUp P 20:30 - 22:30 ~ 2.00 ~ WHSUR ~ P 22:30 - 23:00 I 0.501 PULL I P 23:00 - 00:00 1.00 I PULL P 12/20/2009 00:00 - 01:00 1.001 PULL P Spud Date: 5/25/1982 Start: 12/14/2009 End: 12/28/2009 Rig Release: 12/28/2009 Rig Number: Phase Description of Operations DECOMP CREW, WSL. -DRAIN TREE AND NOTICED K-PLUG APPEARED TO HAVE SMALL LEAK. CAMERON RESEATED DART AND PROBLEM WAS RESOLVED. MONITOR WELL. -BLEED-OFF CONTROL LINES. -N/D TREE. -BARRIERS ARE K-PLUG AND TUBING HANGER PACK OFF. -USE CONSTANT HOLE-FILL AND LOSE 20-BPH TO WELL. -LOAD AND STRAP 5" DRILLPIPE IN PIPE SHED. DRILLPIPE WILL BE RABBITTED ON THE PIPE SKATE AS EACH JOINT IS PICKED UP. DECOMP BOPE. MOVE COME-ALONGS ON BOP STACK TO LINE UP DRILLING RISER. AIR UP AIR BOOTS ON DRILLING RISER. -CHANGE OUT SAVER SUB AND BACKUP GRABBER DIES TO ACCOMMODATE 5" DRILLPIPE. -FUNCTION TEST RAMS. -CONTINUE LOADING AND STRAPPING 5" DRILLPIPE IN PIPE SHED. DECOMP I H y.s- tsFilNt I V, BEGIN BOPE TESTING. -TEST THE HYDRIL TO 250-psi LOW AND 3500-psi HIGH ONLY WITH THE 5" TEST JOINT. MAKE ALL OTHER TESTS TO 250-psi LOW AND 4000-psi HIGH. TEST 4-1/2" VBRs WITH 5" AND 7" TEST JOINTS. ALL TESTS CHART-RECORDED FOR 5-MINUTES, EACH. -GOOD TESTS. -LOSSES AT 22 BPH AVERAGE THROUGH OUT BOP TEST. -BOP TEST WITNESSED BY WSLs MIKE ROONEY, JOHN WILLOUGHBY AND TOOL PUSHERS SAM DYE AND GLENN HERMANN. AOGCC REPRESENTATIVE BOB NOBLE WAIVED STATE'S RIGHT TO WITNESS ON 12/17/2009. DECOMP PJSM. R/U DUTCH RISER. -PULL DART. -P/U LUBRICATOR AND TEST TO 500 PSI. -GOOD TEST. -PULL K-PLUG AND UD. -INSTALL MOUSE HOLE. -BREAK DOW N TEST JOINTS AND UD. DECOMP PJSM. P/U BHA CONSISTING OF: 2-7/8" BULL NOSE, 5-1/2" SPEAR PACK OFF, 2 EA-ITCO SPEAR 4.805 NOM CATCH, AND XO. -RIH AND SPEAR HANGER AND TUBING. DECOMP BACK OUT LOCK DOWN SCREWS. -P/U TO 200K AND SLACK OFF. -P/U TO 235K AND TUBING CAME FREE WITH 175K PICK UP WEIGHT. -PULL HANGER TO FOOR. HANGER HAD GOTTEN HUNG UP ON RISER. WORK HANGER TO SIDE AND P/U TO FLOOR. CHECK RISER BOOTS AND NOTICED BOOTS WHERE PULLED FREE. REPAIRED BOOTS PRIOR TO CIRCULATING B/U. DECOMP CIRCULATE BOTTOMS UP AT 6.5 BPM WITH 440 PSI. Punted: invzuiu iz:~i:uurun BP EXPLORATION Page 3 of 10 Operations Sumrnary Report Legal Well Name: 13-22 Common Well Name: 13-22 Spud Date: 5/25/1982 Event Name: WORKOVER Start: 12/14/2009 End: 12/28/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2009 Rig Name: DOYON 16 Rig Number: i Date From - To Hours Task Code NPT Phase Description of Operations 12/20/2009 00:00 - 01:00 1.00 PULL P DECOMP -DYNAMIC LOSS RATE OF 48 BPH. -R/U CAMCO CONTROL LINE SPOOLER. -R/U POWER TONGS. 01:00 - 12:30 11.50 PULL P DECOMP PJSM AND UD SPEAR AND HANGER ASSY. -POH UD 5-1/2" 17# L-80 TBG FROM 9080' -STATIC LOSS RATE AT 0400-hrs IS 24 BPH. -UD SSSV AT 0600-Hrs, RECOVERED 26 CLAMPS AND 3-SS BANDS, UD THE 5-1/2" OTIS FLOW COUPLING. -UD #75 AT 0630-Hrs; #90 UD AT 0715-Hrs; CUTOFF TO RIG FLOOR AT 1200-Hrs. 12:30 - 13:00 0.50 PULL P DECOMP CLEAR AND CLEAN RIG FLOOR. 13:00 - 15:00 2.00 CLEAN P DECOMP P/U AND INSTALL WEAR BUSHING. R/U 5" HANDLING EQUIPMENT. CONSTANT HOLE-FILL LOSS RATE IS 30-BPH. 15:00 - 16:00 1.00 CLEAN P DECOMP SERVICE RIG AND PIPE SKATE. CONTINUE TO USE CONSTANT HOLE-FILL WITH LOSS RATE OF 30-BPH. 16:00 - 17:30 1.50 CLEAN P DECOMP WAIT ON FULL JOINT OF 4-1/2" TO MAKE A 20' MULESHOE FOR CHECKING THE ID OF THE CUTOFF JOINT. -CONSTANT HOLE FILL LOSS RATE IS 30-BPH. 17:30 - 00:00 6.50 CLEAN P DECOMP PJSM-M/U SCAPER BHA WITH 4-1/2" MULE SHOE. -BHA CONSISTING OF: 4-1/2" MULE SHOE, XO, DOUBLE PIN SUB, 9-5/8" CSG SCAPER, BIT SUB, XO, 4-3/4" DRILL COLLARS. -RIH TO 2400' P/U 5" DRILL PIPE. -SCRAPE FROM 2363' TO 2450' 4 TIMES. -PUMP 20 BBL HI-VIS SWEEP AT 6.7 BPM AND 231 PSI. SMALL AMOUNT OF WHAT LOOKS LIKE PARAFIN AND SAND SEEN AT SHAKERS. DYNAMIC LOSS RATE DURING THIS TIME WAS 35 BPH. -BLOW DOWN TOP DRIVE AND CONTINUE RIH PICKING UP DP. -CONSTANT HOLE FILL LOSS RATE IS 30 BPH. 12/21/2009 00:00 - 02:30 2.50 CLEAN P DECOMP CONTINUE TO RIH PICKING UP 5" DRILL PIPE. -RIH FROM 3513' TO 7294'. -ELEVATORS BECAME BOUND UP ON THE HARD BAND OF JOINT #217. -PUT THE 30K BLOCK WEIGHT DOWN ON ELEVATORS TO ATTEMPT TO FREE UP WITHOUT SUCCESS. -CONSTANT HOLE FILL LOSS RATE IS 30 BPH. 02:30 - 05:00 2.50 CLEAN N SFAL DECOMP PJSM FOR JOB SCOPE CHANGE WITH CREW AND WSL. DISCUSS HAZARDS INVOLVED SUCH AS STEAM, SLIPS TRIPS AND FALLS DUE TO SLICK FLOOR, SWINGING HAMMERS, ELEVATORS COMING FREE DROPPING TO FLOOR, LAYING DOWN JOINT OF PIPE WITH ELEVATORS STILL ATTACHED-BALANCED LOADS. DROPPED OBJECTS, LINE OF FIRE. -STEAM ELEVATORS AND JOINT. -UD JOINT WITH ELEVATORS. KICK OUT 11 MORE JOINTS THAT HAD 7-1/8" NEW HARD BAND SAME SIZE AS THE ONE STUCK IN THE ELEVATOR. -ORDER 15 MORE JOINTS FROM API TO REPLACE THE JOINTS KICKED OUT. THESE WILL BE THE LAST JOINTS IN THE HOLE. rnmea: unreu~u ic.~nuu rm BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: 13-22 Common Well Name: 13-22 Spud Date: 5/25/1982 Event Name: WORKOVER Start: 12/14/2009 End: 12/28/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2009 Rig Name: DOYON 16 Rig Number: Date From - Tc Hours Task 'Code NPT Phase Description of Operations 12/21/2009 02:30 - 05:00 2.50 CLEAN N SFAL DECOMP -CHECK PIPE TALLY AND RECONFIGURE TO ENSURE CORRECT TALLY. -CONSTANT HOLE FILL LOSS RATE IS 24 BPH. 05:00 - 08:00 3.00 CLEAN P DECOMP CONTINUE TO RIH P/U 5" DRILL PIPE FROM 7294'. LOAD 15-JOINTS OF REPLACEMENT DP IN PIPE SHED, STRAP, AND TALLY. -P/U AND M/U JT #275, P/U WT 232-K-Ibs, S/O WT192-K-Ibs, START PUMP AND BRING UP TO 2-1/2-BPM AT 30-psi. TOOK 2-Bbls TO FILL THE DP. -SLOWLY RIH AND FIND TOP OF STUB AT 9083'. STACK OUT _1000-LBS. P/U AND SLOWLY ROTATE WHILE RIH AND SLIP EASILY INSIDE THE STUB. SEE -10-psi WHEN ENTERING. CONTINUE IN 19'. -STOP PUMPING, POH AND P/U, M/U #276, SLOWLY RIH WITH PUMP ON; GET IN 20' WITH THE 4-1/2" MULESHOE STINGER AND SEE PRESSURE INCREASE 200-psi AND STACK OUT ON COLLAR. -P/U TO CIRCULATE A SWEEP. -TOP OF TUBING STUB AT 9083', MAX DEPTH OF MULESHOE IS 9103'. 08:00 - 09:30 1.50 CLEAN P DECOMP CIRCULATE A 20-Bbl HI-VIS SWEEP, 10-BPM AT 815-psi. GET -2-3-GALLONS OF SAND IN RETURNS ACROSS THE SHAKERS WHEN THE SWEEP CAME AROUND. -RIH WITH 4-1/2" MULESHOE TO VERIFY RE-ENTRY. NEED TO ROTATE SLOWLY TO RE-ENTER, BUT SEE NO RESISTANCE WHILE RUNNING DOWN TO THE SHOULDER ON THE MULESHOED JOINT.. 09:30 - 17:00 7.50 CLEAN P DECOMP PJSM TO POH AND UD -6000' OF DP AND S/B REMAINDER AND ALSO THE DCS. -CREW DISCUSSED HAZARDS ASSOCIATED WITH LATCHING, P/U, AND UD DP ON THE PIPE SKATE. PIPE SHED CREW DISCUSSED THE EXCLUSION ZONE AND ROLLING DP OFF THE PIPE SKATE. FORKLIFT OPERATOR ASKED PIPE SHED CREW TO BE AWARE OF THE PIPE HE WILL P/U AND REMOVE FROM THE SHED. -POH AND UD 5" DP. -DP jt #90 UD AT 1300-Hrs; JT #174 UD AT 1445-Hrs. -START S/B 30-STANDS OF DP AT 1500-Hrs. S/B THE DCS AT 1600-Hrs. 17:00 - 17:30 0.50 CLEAN P DECOMP CLEAR AND CLEAN RIG FLOOR. 17:30 - 22:00 4.50 CLEAN P DECOMP PJSM. M/U RTTS. -RIH AND SET RTTS CENTER OF ELEMENT AT 3000' TO PT FROM THE RTTS TO THE COMPOSIT PL G A 9145 . -R/U AND PRESSURE UP TO 2500 PSI WITH 46 STROKES. HOLD FOR 10 CHARTED MINUTES. ROCK SOLID TEST. -RELEASE RTTS. -P/U TO 2500'. SET RTTS. -CONTINUOUS HOLE FILL LOSSES AT 25 BPH. 22:00 - 22:30 0.50 CLEAN P DECOMP SERVICE RIG. -INVESTIGATE AND STOP SNOW MELT LEAK. 22:30 - 00:00 1.50 CLEAN P DECOMP SHUT IN RAMS AND PRESSURE UP TO 4100 PSI. -100 PSI LOST IN THE FIRST 15 MIN. NO FLATLINE TREND. -PRESSURE BACK UP AND ISOLATE MUD PUMPS WITH 2 rnmea: vn¢uiu rc.~i:uu rnn • BP EXPLORATION Page 5 of 10 Operations;Summary Report Legal Well Name: 13-22 Common Well Name: 13-22 Spud Date: 5/25/1982 Event Name: WORKOVER Start: 12/14/2009 End: 12/28/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/21/2009 ~ 22:30 - 00:00 ~ 1.50 ~ CLEAN ~ P ~ ~ DECOMP VALVES. 12/22/2009 00:00 - 02:00 2.001 EVAL P 02:00 - 04:30 ~ 2.50 ~ EVAL ~ P 04:30 - 19:00 14.501 CASE P 19:00 - 00:00 ( 5.001 CASE ~ P 112/23/2009 100:00 - 05:30 I 5.501 CASE I P 05:30 - 07:30 2.001 CASE ~ P -100 PSI LOST IN THE FIRST 15 MIN. 100 PSI LOST IN THE SECOND 15 MIN. -SPOKE WITH ADW RWO ENGINEER AND IT WAS DECIDED TO P/U -40' AND REATTEMPT TEST. TIE61 RELEASE RTTS AND P/U TO 2463' -SET RTTS PRESSURE UP TO 4100 PSI FROM THE RTTS TO SURFACE FOR 30 CHARTED MIN. -75 PSI LOST IN THE FIRST 15 MIN. AND 25 PSI IN THE SECOND 15 MIN. GOOD TEST TIE61 PJSM FOR POH. -RELEASE RTTS AND CIRCULATED A B/U AT 6.5 BPM AND 150 PSI. -MONITOR WELL -WELL STATIC. -POH AND L/D RTTS. -CLEAN AND CLEAR RIG FLOOR. -WHILE DRIFTING PIPE IT WAS DISCOVERED THAT WE HAD A MIX OF 7" 26# AND 29# CSG. -NOTIFIED TOWN ENGINEER AND DISCUSSED SITUATION. WILL ATTEMPT TO REPLACE 29# WITH 26# AND IF NO OTHER ALTERNATIVE, RUN A MIXED STRING WITH 29# ON TOP OF STRING. -CONSTANT HOLE FILL LOSS RATE OF 25 BPH. -SORT OUT PIPE IN YARD AND DETERMINE HOW MUCH 26# AND 29# PIPE IS ON LOCATION. TIEB1 PJSM -RE ORGANIZE 7" TUBULARS IN PIPE SHED AND STRAP AND DRIFT PIPE. THE 29# PIPE IS SEPARATED FROM THE 26# AND IDENTIFIED WITH TAPE. IF IT HAS TO BE UTILIZED, IT WILL BE THE LAST PIPE RIH, HENCE IT IS ON THE BOTTOM AND ON THE OUTBOARD SIDE OF THE ROW. -R/U 7" CASING HANDLING EQUIPMENT. -0830-Hrs, JOINT #74 STRAPPED. -0840-Hrs, 10-JOINTS OF 7", 26#, L-80, BTC-M DELIVERED BY HOT-SHOT TRUCK FROM STORES. -COMPLETE PIPE TALLY. -CONSTANT HOLE FILL LOSS RATE OF 26 BPH. TIEB1 PJSM RIH WITH 4-1/2" MULE SHOE JOINT AND ALL J EW LERY. -CHECK FLOATS -GOOD. -RIH TO JT 90 - 7" 26# L-80 BTC-M SCAB LINER. -FILLING PIPE EVERY 5 JTS. -CONSTANT HOLE FILL LOSS RATE OF 40 BPH. TIEB1 CONTINUE TO RIH FROM JT 90 TO JT 162. -RIH WITH PACKER ~ 0400 hrs. -R/D 7" HANDLING EQUIPMENT. -CHANGE OUT ELEVATORS. -CIRCULATE LINER VOLUME. PUMP RATE OF 6 BPM ~ 180 PSI. -RIH WITH 5" DP CONSTANT HOLE FILL LOSSES AT 22 BPH. TIEB1 RIH WITH 7" 26# I-80 BTC-M LINER ON 5" DP FROM 6708' rnrnea: invzuiu icsruurm BP EXPLORATION Page 6 of 10 Operations Summary`Report Legal Well Name: 13-22 Common Well Name: 13-22 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 12/23/2009 05:30 - 07:30 2.00 CASE P 07:30 - 08:00 0.50 CASE P 08:00 - 09:00 1.00 CEMT P 09:00 - 09:30 0.50 CEMT P 09:30 - 10:00 0.50 CEMT P 10:00 - 11:00 1.00 CEMT P 11:00 - 12:30 1.50 CEMT P 12:30 - 13:30 1.00 CEMT P 13:00 - 14:00 1.00 CEMT P Spud Date: 5/25/1982 Start: 12/14/2009 End: 12/28/2009 Rig Release: 12/28/2009 Rig Number: .Phase Description of Operations TIE61 TO 9018' UP WT = 230K, DN WT = 205K, SLACK OFF SLOWLY AND TAG UP ON 5-1/2' TUBING STUB WITH PORTED SUB ON DEPTH, PLACING 4-1/2" MULE SHOE AT 9103'. POH LAY DOWN SINGLE. TIEB1 PJSM, COVERING PICKING UP PUP JOINTS AND BAKER CEMENT HEAD. TIE61 MAKEUP 10' PUP JT ON TOP OF CEMENT HEAD AND P/U HEAD, MAKE UP 15' AND 5' PUP JOINTS ON BOTTOM OF CEMENT HEAD FOR SPACE OUT. SLACK OFF AND NO-GO OUT ON TOP OF 5-1/2" TUBING STUB ~ 9083' PICKUP 2' TO POSTION LINER ON DEPTH. UP WT = 235K, DN WT = 210K. TIEB1 RIG UP CIRCULATING LINES AND BREAK CIRCULATION (~ 5 BPM WITH 350 PSI. HELD PJSM, WITH ALL PERSONNEL INVOLED IN CEMENT JOB. TIE61 PUMP 5 BBLS WATER AND TEST LINES TO 4,500 PSI, PUMP 45 BBLS WATER ~ 5 BPM 475 PSI. TIEB1 BATCH MIX AND PUMP 197 BBLS CLASS G CEMENT WEIGHTED TO 15.8 PPG, (954 SXS) YIELD = 1.16, ~ 4.5 BPM, ICP = 380 PSI, FCP = 82 PSI. RELEASE DP WIPER DART AND KICK OUT WITH 5 BBLS WATER FROM SCHLUMBERGER, POSITIVE INDICATION PLUG LEFT THE HEAD. TIE61 SWITCH OF TO RIG AND DISPLACE CEMENT WITH RIG PUMPS ~ 5 BPM, ICP = 150 PSI, SLOWED DISPLACEMENT RATE TO 3 BPM 33 BBLS INTO DISPLACEMENT TO PICKUP LINER WIPER PLUG, DID NOT SEE LATCH, INCREASE RATE TO 5 BPM, CAUGHT UP WITH CEMENT 143 BBLS INTO DISPLACMENT, SLOWED RATE TO 2 BPM WITH 258 BBLS PUMPED TO KEEP CIRCULATING PRESSURE UNDER 3100 PSI, CONTINE SLOWLY DECREASING PUMP RATE TO KEEP FROM SETTING ZXP LINER TOP PACKER, (LINER HANGER IS ALREADY SET) FINAL CIRCULATING RATE WAS 1 BPM WITH 3400 PSI, BUMPED PLUG WITH CALCULATED STROKES (3420 STKS), PRESSURED UP TO 3750 PSI AND HYDRAULIC PUSHER TOOL CYCLED. SHUT DOWN PUMPS, HELD PRESSURE FOR 5 MIN, BLED OFF AND CHECK FLOATS, FLOATS HELD. CIP ~ 12:28 HRS. TIEBi SHUT LOWER TIW VALVE ON CEMENT HEAD AND BLOW DOWN CEMENT LINE THROUGH TOP DRIVE, REMOVE CEMENT HOSE AND INSTALL PLUG ON CEMENT HEAD. ROTATE STRING 20 TURNS TO THE RIGHT TO RELEASE RUNNING TOOL, 5 RPM, 1 K TORQUE. PRESSURE UP TO 1,000 PSI, PICKUP AND EXPOSE ROTATING DOG SUB AND CIRCULATE 20 BBLS AT 7 BPM, 125 PSI TO CLEAR CEMENT FROM TOP OF THE LINER, SLACK OFF AND SET DOWN 45K TO ENSURE ZXP IS SET SAW INDICATION OF PACKER FULLY SETTING, REPEAT THIS PROCESS WITH ROTATION 15 RPM, 1K TORQUE SET DOWN 45K. TOP OF , ZXP LINER TOP PACKER ~ 2392' TIE61 CBU TO CLEAR CEMENT FROM ABOVE PACKER AT 7 BPM Printed: 1/11/2010 12:37:00 PM BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: 13-22 Common Well Name: 13-22 Spud Date: 5/25/1982 Event Name: WORKOVER Start: 12/14/2009 End: 12/28/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2009 Rig Name: DOYON 16 Rig Number: Date -From - To Hours Task ~ Code NPT Phase Description of Operations 12/23/2009 13:00 - 14:00 1.00 CEMT P TIE61 200 PSI PUMP 20 CITRIC PILL, TAKING RETURNS TO CUTTINGS TANK, 17 BBLS CEMENT RETURNED TO SURFACE. CBU iX ~ 12 BPM 560 PSI RECIPROCATE STRING 50' STROKES. 14:00 - 18:30 4.50 CEMT P TIEB1 PJSM -BREAK OUT AND LAY DOWN CEMENT HEAD. -BLOW DOWN TOP DRIVE. -UD 5' DRILL PIPE. -UD LINER RUNNING TOOL. -14:15-hrs 24 NOTICE WAS GIVEN TO AOGCC FOR UPCOMING BOP TEST. 18:30 - 19:30 1.00 CEMT P TIEB1 M/U STACKER WASHER. -RIH AND FLUSH BOP STACK WITH BLACK WATER PILL. -FUNCTION ALL RAM. -FLUSH BOP STACK AGAIN. -BLOW DOWN TOP DRIVE. -UD STACKER WASHER. 19:30 - 21:00 1.50 CASE P TIE61 R/U EQUIPMENT. -AT 20:00 hrs: 500 PSI COMPRESSIVE STRENGTH OBTAINED IN 7 hrs 7 min. PRESSURE TEST 9-5/8" CSG AND 7" LINER TO 4050 PSI FOR 30 CHARTED MINUTES. LOST 75 PSI IN THE FIRST 15 MIN. AND FLATLINED FOR THE 2ND 15 MINUTES. -GOOD TEST. -R/D CHART AND LINES. 21:00 - 00:00 3.00 BOPSU P TIE61 PJSM -DRAIN STACK. -BARRIERS: COMPOSITE BRIDGE PLUG AND CEMENTED SCAB LINER. -BLOW DOWN ALL LINES. TURN BUCKLES AND BODE STACK. -PULL TUBING SPOOL. -23:14 hrs JEFF JONES WAIVED STATES RIGHT TO WITNESS UPCOMING BOP TEST. 12/24/2009 00:00 - 03:00 3.00 WHSUR P CLEAN PJSM -R/U AND PULL PACKOFF. -INSTALL NEW REPLACEMENT CONVERSION PACK OAF MANDREL HANGER TYPE TSM-NS1. -N/U NEW 13-5/8" TUBING SPOOL. -TEST PACKOFF TO 5000 PSI FOR 30 MINUTES. -GOOD TEST -C/O SAVER SUB TO 4" HT-38. 03:00 - 06:00 3.00 BOPSU P CLEAN PJSM -N/U 13-5/8" BODE STACK. -CHANGE OUT RAMS FROM 4-1/2" X 7" VBRs TO 3-1/2" X 6" VBRs. 06:00 - 06:30 0.50 BOPSU P CLEAN PJSM, COVERING RIG UP AND TEST BOP EQUIPMENT. RIG UP BOP TEST EQUIPMENT. 06:30 - 09:30 3.00 BOPSU P CLEAN TEST BODE TO 250 PSI LOW 4000 PSI HIGH PER DOYON, BP AND AOGCC BEGS. TEST 3 1/2" X 6" VBR'S WITH 4" AND 5-1/2" TEST JOINTS, AOGCC REP JEFF JONES WAIVED WITNESS OF BOP TEST, 24 HR NOTICE GIVEN. TEST WITNESSED BY WSL BRIAN BUZBY AND DOYON TOOLPUSHER SAM DYE. 09:30 - 10:00 0.50 BOPSU P CLEAN DRAIN STACK AND CHANGE OUT BLIND RAM DOOR SEALS. rnnrea: u~vcvw ic[oi v~nw i • BP EXPLORATION Page 8 of 10 Opelrations S'urnmary Report Legal Well Name: 13-22 Common Well Name: 13-22 Spud Date: 5/25/1982 Event Name: WORKOVER Start: 12/14/2009 End: 12/28/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2009 Rig Name: DOYON 16 Rig Number: i Date ~ From - To Hours ~ Task Code NPT Phase Description of Operations 12/24/2009 10:00 - 14:00 4.00 BOPSU P CLEAN SUSPEND RIG OPERATIONS TO ALLOW CREWS TO GO TO CAMP FOR CHRISTMAS DINNER AND ENJOY A LITTLE R&R. 14:00 - 20:00 6.00 BOPSU P CLEAN CONTINUE TESTING BOPE. -TEST WITH 5-1/2" TEST JOINT. -FUNCTION AND RETEST LOWER IBOP -GOOD TEST. -ACCUMULATOR TEST. -ALL TESTS CHARTED. ALL TESTS PASS. -RIG DOWN TEST EQUIPMENT. -INSTALL WEAR BUSHING. 20:00 - 21:00 1.00 CLEAN P CLEAN PJSM - P/U 6-1/8" CLEAN OUT BHA. -BHA CONSISTS OF: 6-1/8" USED BIT, BIT SUB, BOWEN BUMPER SUB, XO SUB, DRILL COLLARS. -RIH. 21:00 - 00:00 3.00 CLEAN P CLEAN RIH PICKING UP 4" DRILL PIPE. -RIH FROM 290.14' to 2820'. 12/25/2009 00:00 - 04:30 4.50 CLEAN P CLEAN CONTINUE TO RIH P/U 4" DRILL PIPE. -RIH FROM 2820' TO 8921' 04:30 - 06:00 1.50 CLEAN P CLEAN PJSM. SLIP AND CUT DRILLING LINE. SERVICE DRAW WORKS AND ADJUST BRAKES. 06:00 - 06:30 0.50 CLEAN P CLEAN BREAK CIRCULATION AND OBTAIN DRILLING PARAMETERS, UP WT = 175K, DN WT = 135K, RT WT = 155K, 60 RPM, 6K TORQUE. WASH DOWN AND TAG CEMENT ~ 8930' 06:30 - 10:00 3.50 CLEAN P CLEAN DRILL CEMENT FROM 8930 TO LANDING COLLAR, TAGGED LANDING COLLAR ~ 9009', 5' HIGH DRILL PLUGS AND LANDING COLLAR FROM 9009' TO 9012' WITH 5-15K WOB, 60-80 RPM, TORQUE 6K, 2-8 BPM, 975- 1700 PSI. 10:00 - 11:30 1.50 CLEAN P CLEAN DRILL CEMENT FROM 9012' WITH ABOVE PARAMETERS TO PORTED SUB ~ 9074' BOTH FLOAT COLLAR AND PORTED SUB WHERE TAGGED 5' HIGH. 11:30 - 12:30 1.00 CLEAN P CLEAN CBU X 2 , 500 GPM ~ 3100 PSI, ROTATE 80 RPM, 6K TORQUE RECIPROCATE PIPE 80' STROKES. 12:30 - 13:30 1.00 CLEAN P CLEAN PUMP 20 BBL HIGH VIS SPACER AND DISPLACE WELL FROM 9.8 PPG BRINE TO SEAWATER AT 500 GPM 2800 PSI .RECIPROCATE PIPE DURING DISPLACMENT. 13:30 - 14:00 0.50 CLEAN P CLEAN MONITOR WELL -STATIC, BLOW DOWN TOP DRIVE 14:00 - 18:00 4.00 CLEAN P CLEAN POH WITH CLEAN OUT ASSEMBLY FROM 9078' TO 290' -STAND BACK DRILL COLLARS. 18:00 - 19:00 1.00 CLEAN P CLEAN UD 6-1/8" CLEAN OUT BHA. -P/U 3-5/8" CLEAN OUT ASSEMBLY TO FLOOR. 19:00 - 19:30 0.50 CLEAN P CLEAN PJSM ON SERVICING TOP DRIVE AND INSPECTING ROUGHNECK AND SKATE. DISCUSS DROPPED OBJECTS. -M/U 3-5/8" CLEAN OUT BHA. -DISCUSS PICKING UP 2-7/8" PAC PIPE. 19:30 - 20:00 0.50 CLEAN P CLEAN SERVICE TOP DRIVE. -INSPECT IRON ROUGHNECK AND SKATE. -GREASE BLOCKS. 20:00 - 00:00 4.00 CLEAN P CLEAN RIH. -RIH OUT OF DERRICK FROM 538.18 TO 5277' 12/26/2009 00:00 - 01:00 1.00 CLEAN P CLEAN RIH FROM 5277' TO 9073'. -BREAK CIRCULATION AT 2.5-BPM WITH 410-PSI. CIRCULATE WHILE STRAP AND TALLY 4.5" TUBING. rnnted: tnvzutu tz::truurnn • BP EXPLORATION Page 9 of 10`' Operations Summary .Report Legal Well Name: 13-22 Common Well Name: 13-22 Spud Date: 5/25/1982 Event Name: WORKOVER Start: 12/14/2009 End: 12/28/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2009 Rig Name: DOYON 16 Rig Number: Date From - To j Hours Task Code NPT Phase Description of operations 12/26/2009 01:00 - 05:00 4.00 CLEAN P CLEAN STRAP AND DRIFT 4-1/2" L-80 TCII TUBING PRIOR TO DRILLING OUT COMPOSITE BRIDGE PLUG AND POOH L/D 4" DP. 05:00 - 07:00 2.00 CLEAN P CLEAN R/D CEMENT LINE. -176K UP, 140K DOWN, 4.5 BPM AT 780 PSI. RPM AT 60 WITH 7K FREE TQ. AND 156K WT. -M/U STAND AND WASH DOWN TO 9074'. -DRILL CEMENT FROM 9074' TO 9100'. -WASH DOWN TO TOP OF PLUG AT 9147' AND DRILL 07:00 - 16:00 I 9.001 CLEAN I P 16:00 - 17:00 1.001 CLEAN P 17:00 - 17:30 0.501 CLEAN P 17:30 - 21:00 I 3.50 21:00 - 00:00 I 3.00 12/27/2009 00:00 - 23:00 23.00 23:00 - 00:00 I 1.00 12/28/2009 100:00 - 01:00 I 1.00 COMPOSITE BRIDGE PLUG TO 9151'. -WASH DOWN TO 9175' AND DRILL COMPOSITE PLUG TO 9180' LOST TOTAL RETURNS. -DYNAMIC LOSS RATE OF 400 BPH. -CONTINUE TO WASH DOWN TO 9208'. -R/U TO PUMP DOWN BOTH SIDES AT 8 BPM. PUMPED 60 BBLS AWAY WITHOUT FILLING HOLE. -BLOW DOWN TOP DRIVE. CLEAN POH L/D 4" DRILL PIPE. -POH FROM 9208' TO 538'. -FILLING AT 60 BBLS AND HOUR. CLEAN R/U TO L/D 2-7/8" PAC. -UD PAC PIPE AND BHA. CLEAN ESTABLISH LOSS RATES. -LOSS RATE OF 198 BPH. RUNCMP PULL WEAR RING. -P/U COMPENSATOR, TONGS, LONG BAILS, ELEVATORS. -R/U EQUIPMENT TO RUN 4-1/2" 12.6# L-80 TCII TUBING. -M/U XO WITH FLOOR VALVE. RUNCMP PJSM FOR RUNNING COMPLETION. DISCUSSING DROPPED OBJECTS, PINCH POINTS, ETC. -RUN 4-1/2" 12.6# L-80 TCII TUBING TO 1184' JT #24. -FILLING HOLE AT 60 BPH. RUNCMP CONTINUE TO RIH WITH 4-1/2" 12.6# L-80 TCII TUBING. -RIH FROM 1184' TO 8996'. -REPLACE COLLAR ON JT #51. -HAD TO CLEAN AND EMMERY CLOTH ALL CASING COLLARS AND PIN ENDS TO ACHIEVE PROPER MAKE UP. DUE TO THE LAST 5 OR SIX THREADS ON PIN ENDS WERE ROUGH NOT ALLOWING FOR PROPER MAKE UP. BACKED OUT EVERY OTHER JT AND RETORQUED. DID NOT HAVE TO LAY ANY 4-1/2" JTS DOWN. -HAD THE SAME ISSUES WITH THE 5-1/2" TUBING. -LAYED JT #28 (40.30') DOWN AND REPLACED WITH JT #58 (40.45'). CHANGED COLLAR ON JT #29. -TORQUE TURNED AlL CONNECTIONS. -USED JET LUBE SEAL GUARD ON CONNECTIONS. -TOTAL JTS RAN 4-1/2" = 154 JTS, 5-12" = 56 JTS PLUS 19' PUP ONE FULL JT UNDER TUBING HANGER. -UP WEIGHT 150K AND DOWN WEIGHT 132K. RUNCMP M/U HANGER AND LANDING JT. RUNCMP CONTINUE TO M/U HANGER AND LANDING JT. -RIH AND LAND 22' IN ON LANDING JT. Printed: 1/11/2010 12:37:00 PM BP EXPLORATION Page 10 of 10 .Operations Summary Report Legal Well Name: 13-22 Common Well Name: 13-22 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 12/28/2009 00:00 - 01:00 1.00 BUNCO 01:00 - 03:30 2.50 BUNCO 03:30 - 04:30 1.00 BUNCO 04:30 - 08:00 3.50 BUNCO P 08:00 - 09:00 1.00 BUNCO 09:00 - 10:30 1.50 BOPSU P 10:30 - 12:00 1.50 WHSUR P 12:00 - 17:00 5.00 WHSUR P Spud Date: 5/25/1982 Start: 12/14/2009 End: 12/28/2009 Rig Release: 12/28/2009 Rig Number: Phase Description of Operations RUNCMP -RILDS. -R/U CIRCULATION LINES. AND PRESSURE TEST LINES TO 4000 PSI. RUNCMP PJSM WITH ALL HANDS AND VAC TRUCK DRIVERS. -REVERSE CIRCULATE AT 3 BPM WITH 10 PSI 150 BBLS OF 9.0 PPG BRINE 120 DEGREES. GOT RETURNS 70 BBLS AWAY. -REVERSE CIRCULATE 225 BBLS OF 9.0 PPG BRINE WITH CORROSION INHIBITOR 120 DEGREES. RELIEVED RETURNS 70 BBLS AWAY. RUNCMP PJSM, R/U LITTLE RED AND PRESSURE TEST LINES TO 4,000 PSI. -REVERSE CIRCULATE 100 BBLS OF 80 DEGREE DIESEL DOWN THE IA AT 3 BPM AND 200 PSI NO RETURNS. RUNCMP DROP BALL AND ROD. PUMP 22 BBLS DIESEL DOWN IN PRESSURE UP TO 4000 PSI TO SET PACKER AND TEST TUBING. SAW INDICATION OF PACKER SETTING AT 1800 PSI CONTINUE TO PRESSURE UP TO 4,000 PSI HELD FOR 30 MIN RECORD ON CHART. BLED TUBING ~~ PRESSURE TO 1500 PSI. LINE UP ON IA AND LITTLE RED ', FILLED IA WITH DIESEL (31 BBLS) PRESSURE UP TO 500 PSI BLED OF TO GET AIR OUT PRESSURE UP TO 4,000 PSI AND HELD FOR 30 MIN. RECORD ON CHART. GOOD TEST BLED OFF BOTH TUBING AND IA. RUNCMP CAMERON DRY ROD IN TWC, AND TEST FROM ABOVE TO ', 4,000 PSI. BLOW DOWN CIRCULATING LINES. RUNCMP PJSM, PULL RISER AND NIPPLE DOWN BOP. WHDTRE NIPPLE UP 13-5/8" X 6 3/8" ADAPTER FLANGE AND TEST SEALS TO 5,000 PSI. -GOOD TEST WHDTRE NIPPLE UP 6-3/8" 5000 TREE. -TEST TREE TO 5000 PSI FOR 10 MIN. -GOOD TEST -EMPTY AND CLEAN PITS. -RELEASE RIG AT 17:00 HRS. Printetl: 1/11/2010 12:37:00 PM TREE _ . GRAY GEN 2 Wk1LHEAD= GRAY ACTUATOR = AXELSON KB. ELEV - 84 BF. ELEV - KOP = 3000' Max Angle = 32 @ 6500' Datum MD = 9574' Datum TV D = 8800' SS ~R~-.{~„'t CRAFT AFETY NOTES: 13-22 2023' ~--~5-1/2" HES 9Q-X-Nip, ID=4.562" 5-1/2" TBG, 17#, L-80, TGII, .02325 bpf 2336' 2336' -15-1/2" X 4-1/2" L-80 CROSSOVER Minimum ID = 3.725" @ 9006' 2392' 9-5/8" x 7" Baker ZXPLiner Top Packer 4-1/2" HES XN NIPPLE 13-3/8" CSG, 72#, L-80, ID = 12.347" 2520' 8865' 4-1/2" HES 9G X-Nip, ID=3.812" 8, 891' 7" x 4-1 /2" HES TNT Packer, ID = 3.856" 7" LNR ,26#, L-80, BTGM,.03826 bpf, ID = 6.276" 9078' 8933' 4-1/2" HES 9Cr X-Nip, ID=3.813" 7" x 4-1/2" L-80, Ported sub crossover 9078' 9,006' 4-1/2" HES 9Cr XN-Nip, ID = 3.725" 4-1/2" TBG ,12.6#, L-80, TGII, .01522 bpf 9018' 9018' 4-1/2" HES, 9Cr,WLEG, ID = 3.958" 4-1/2" Mule Shoe, 12.6#, L-80, .0152 bpf 9100' 9117' 9-5/8" X 5-1/2" BOT 3-H PKR 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 9202' g12g' S-1/2" X 4-1/2" XO, IS = 3.958 TOP OF 4-1/2" TBG-PC 9129' TOP OF 7" LNR 9155' - 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 9202' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9455' PERFORATION SUMMARY REF LOG: BHCS ON 06/07/82 ANGLE AT TOP PERF: 13 @ 9460' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9460-9480 O 09/16/91 3-3/8" 4 9566-9586 O 11/07/82 3-3/8" 4 9592-9622 O 11/07/82 3-3/8" 4 9632-9658 O 11/07/82 3-3/8" 4 9662-9672 O 11/07/82 3-3/8" 4 9678-9688 O 11/07/82 3-3/8" 4 9692-9710 O 11/07/82 3-3/8" 4 9726-9743 O 11/07/82 3-3/8" 4 9755-9770 O 09/16/91 PBTD 9924' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9967' TD 9189' 4-1/2" OTIS XN NIP, ID = 3.725" 9201' ~4-1/2" BOT SHEAROUT SUB 9202' 4-1/2" WLEG, ID = 3.958" 9182' ELMD TT LOGGED 06/15/82 9688' (~ LINER RESTRICTION, ID = 4.20" (07/24/07) I LINER RESTRICTION, ID = 4.98"(07/24/07) ( UNKNOWN ~ FISH: COMPOSffE PLUGS PIECES (12/26/09 DIMS) 9897' FISH - DA 27' X 3-1/2" PERF GUN W/CCL & DECENTRALIZERS; LOST 06/12/82 DATE REV BY COMMENTS DATE REV BY COMMENTS 06/12/82 ORIGINAL COMPLETION 10/27/01 RN/TP CORRECTIONS 12/28/09 D16 RWO 12/30/09 TLH DRLG HO CORRECTIONS PRUDHOE BAY UNff WELL: 13-22 PERMff No: 182-0770 API No: 50-029-20749-00 SEC 14, TION, R14E 2466.33 FEL 2341.15 FNL BP Exploration (Alaska) ~~LL ~E.? ~~~~~~ ®®~,. PROACTIVE DIAfjNOSTIC SERVICES INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907] 793-1225 f~ 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 BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 j Leak Detection - STP 05-Dec-09 13-22 2) ~~~ ~~a -o'~~ rgrs~- 1 BL / EDE 50-029-20,749-0D _.,_. Signed Print Name: Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL ..~i. u t7~.,`?e ~1~,.~..i ^+i71 wEBSITE .+u'` C'\Documznts and Sittings\Diane Will.iams\DzsktoplTransmit_BP.docx • • ~ ~,. ~ ~ ~ ~,~._ ~ ~ ~s , ~ ~~ ~~~~ ~ ~ ~L ' ~ , ~ ~ ~ ~ ~. ~, ~ .; ~ ~~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~~ ' ~ ' SEAN PARNELL, GOVERNOR ~~ ~_~ ~~~ ~ ~ ~ ~~, ~~ ~ ~~ ~, ~~ ~ t~-7~ OIL ~~ <Tt7-~,7 ~ 333 W. 7th AVENUE, SUITE 100 CO~TSERQATIOI~T CO~II~IISSIO~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 , FAX (907) 276-7542 Mr. David Reem Engineering Team Leader BP Exploration (Alaska), Inc. ~~' ~ , Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-22 Sundry Number: 309-335 ~~~N~~ .a~`;; ~ ~ 2~~:~ Dear Mr. Reem: P.O. Box 196612 Anchorage, Alaska 99519-6612 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 Comm.ission 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, ,... DATED this ~ day of October, 2009 Encl. ` ~s~"'f ~~~ STATE OF ALASKA ~"~ ' I ALAS~IL AND GAS CONSERVATION COMM~ON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 -_ - - ~ , ~,~G~ ~ . J-/~ 09 1. Type of Request: ° ^ Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Re-Enter Suspended WeH ~ Alter Casing- "~ Repair Well '^ Plug Perforations ^ Stimulate ^ Other Specify: ^ Change Approved Program -~ Pull Tubing ^ Perforate New Pool ^ Time E~ension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 182'~~~ " 3. Address: ~ Service - ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029•20749-00-00 ', 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 13-22- , Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. Field / Pool(s): ADL 028315 - Prudhoe Bay Field / Prudhoe Bay Oil Pool ~ ~• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): EffeCtive Depth TVD (ft): Plugs (measured): Junk (measured): 9975' -, 9276'- - 9924' 9226' 9189' 9897' Caain Len th Size MD ND Burst Golla e Structural Conductor 7' " 7' 79' 14 47 Surface 2' 1-3/ " 252 ' 2520' 4930 2670 Intermediate 4 5' -5/8" 945 ' 8768' 6870 4760 Produdion Liner 81 ' 7" 91 - 967' 477' - 9268' 160 702 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 9460' - 9770' 8773' - 9075' S-1/2", 17# x 4-1/2", 12.6# L-80 9202' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'3-H' packer Packers and SSSV 9129' / 8452' MD (ft) and ND (R): 12. Attachments: 13. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: DeCember 10, 2009 ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ~ WAG . ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that the foregoing is true and correci to the best of my knowledge. Contact David Bjork, 564-5683 Printed Nam David Reem Title Engineering Team ~eader Prepared By Name/Number Signature Phone 564-5743 Date CJ. 16 ~ Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: No ' Commission so that a representative may witness 3G ~, 33~ Sundry Number: ^ Plug Integrity BOP Test ~Mechanical Integrity Test ^ Location Clearance ,Q .-/~- Other. ~ 7~C~ ~JSL ~Ud~ ( ~S ~ _ ~.~-'' (es fCnic.~. .) J sL ~yn ~dv 2 ~r ~ . . o aer ZO ~}AC. ~5ylZ~d~ ~ ~ - ~4G~Cc.r v~ ~ va-~ilWC.e.. aPprov~ ~° Subsequent Form Required: ~U • APPROVED BY ~ ~ Approved By: COMMISSIONER THE COMMISSION Date Forrn 10-403~e'vised 07/2000 / Subrriit In Duplicaie , R.~'~, t v°^i Q I~ 11 ~ ~ ~~~~i-.~~ ,r~'~ ~~ ~ L `G~ ~-'~`"f ~ f ; ~~ ~ ,~ i 200G /-~ _~, , ~ ~, ~ _._ ~ - ~ 3~, o g • • ~ p GP ~~~~ ~ 13-22i Expense Rig Workover Scope of Work: Pull 5-'/" L-80 completion, cement a 7" scab liner, Replace Casing Pack-offs, run 5-%" x 4-'/ L-80 completion. MASP: 2,410 psi Well Type: Injector Estimated Start Date: Production Engineer: Intervention Engineer: December 10, 2009 Olivia Bommarito David Bjork Pre-Ria Work Request: S 1 Pull PXN plug at 9189' MD. Drift the tubing for a 5-'/z" jet cutter. Set a 4-'/" composite brid e lu in the acker tail i e at 9,160' MD reference tubin tall dated 6/11/82 . F 2 ~luid-pack wellbore and attempt a MIT-T to 1,000 psi, MIT-OA to 2,000 psi, MIT-IA to 1,000 si record LLR as necessa . E 3 Power Jet cut 5-'/2' L-80 tubing at 9,080' MD, in the bottom 10' of the last full joint above the acker reference tubin tall dated 6/11/82 . F 4 Circufate well with 8.6 seawater and freeze rotect to 2000'. W 5 Check the tubing and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. W 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 4-'/i' x 7" VBR's pipe rams. Pressure test Blind Rams and VBR's to 4,000 psi, Annular to 3,500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pul! and LD 5-%Z" tubing string to the cut. 3. RIH with 5" drillpipe and scrape the casing to 9,080' MD. 4. RIH with a RTTS to just above the tubing stub and pressure test the composite bridge plug then PUH to 2,400' and test the casing to surtace. 5. Fully cement a 7" BTC scab liner from ~2,350' to 9,120' MD. (Barriers: 4'/z" x 7" VBR, tested composite plug at 9,160' MD and kill weight fluid) 6. Change 9-5/8" casing packoff. 7. Change 4~'h" x 7" VBR's to 3-'/2" x 6" VBR's and test to 4,000 psi 8. RIH with 4" drillpipe and drill up the 7" shoe tract, then drill up the 4-%" shoe tract and composite plug. 9. Run 5-%2" x 4-%" L-80 completion with a 7" Baker S-3 packer. Position packer at ~9,000' MD. 10. Displace the IA to packer fluid and freeze protect to 2,000' MD. 11. Set the Packe~, test tubing and IA to 4,000 psi. 12. Set BPV. ND BOPE. NU and test tree. RDMO. C~ J 13-22i Expense Rig Workover L~ Scope of Work: Pull 5-'h" L-80 completion, cement a 7" scab liner, Replace Casing Pack-offs, run 5-'h" / x 4-~h L-80 completion. MASP: 2,410 psi Well Type: Injector ~~ Estimated Start Date: December 10, 2009 ~~,~,~ ~~Q Production Engineer: Olivia Bommarito ~~ ~~'~ ~, ~~ y Intervention Engineer: David Bjork ~ ~~. ~~~~~ Pre-Riq Work Request: ~..-"~"~:.: S 1 Pull PXN plug at 9189' MD. Drif the tubing for a 5-'h" jet cutter. Set a 4-~/2" composite brid e lu in the acker tail i at 9,160' MD reference tubin tall dated 6/11/82 . F 2 Fluid-pack wellbore and attem t a MIT-T to 1,000 psi, MIT-OA to 2,000 psi, MIT-IA to 1,000 si record LLR as nece sa . E 3 Power Jet cut 5-'/2" L-80 tu ing at 9,080' MD, in the bottom 10' of the last full joint above the acker referenc tubin tall dated 6/11/82 . F 4 Circulate well with 8.6 eawater and freeze rotect to 2000'. W 5 Check the tubing and ca ng hanger lock down screws for free movement. Completely back out and check e ch lock down screw for breakage (check one at a time). PPPOT-T & IC. W 6 Set a BPV in the tubi han er. O 7 Remove the wellhou e& flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU B PE with 3-'h" x 6" VBR's pipe rams. Pressure test Blind Rams and VBR's to 4,0, 00 psi, Annular to ,500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through th cu . 2. Pull and LD 5-'h" tu mg string to the cut. 3. RIH with a RTTS t just above the tubing stub and pressure test the composite bridge plug then PUH to 2,400' and test e casing to surface. 4. Fully cement a 7" BTC scab liner from ~2,350' to 9,120' MD. (The 3-'h" x 6" VBR will N~T be /? changed to 7" a the barrier to the reservoir will be a tested composite plug at 9,160' MD. 5. Change 9-5/8" asing packoff. 6. RIH and Drill u the 7" shoe tract, then drill up the 4-~/2" shoe tract and composite plug. 7. Run 5-'/2" x 4-'/2" L-80 completion with a 7" Baker S-3 packer. Position packer at --9,000' MD. 8. Displace the IA to packer fluid and freeze protect to 2,000' MD. 9. Set the Packer, test tubing and IA to 4,000 psi. 10. Set BPV. ND BOPE. NU and test tree. RDMO. R~ _• GRAY GE1V 2 WEILHEAD = GRAY ACTUATOR = AX~SON KB. ELEV = 84~ BF. E1EV = ? KOP = 3000' Max Angle = 32 @ 6500' Datum MD = 9574' Datum N D= 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ Minimum ID = 3.725" @ 9189' ~~ 4-1/2" OTIS XN NIPPLE ~~~s+ 16~1C1 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 9129~ TOPOF4-1l2"TBG-PC 9129~ TOP OF 7" LNR ~~ 9155' ',~ 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-~ 9202' 13 ~~ ~ SAFETY NOTES: ***PROD CSG LEAK OPERATING LIM ITS: MAX IAP = 500 PSI; MAX OAP =1000 PSI (02/24/06 WAIV ER~"*` 20~' S-1 /2" HES RMQ SSSV-NIP, ID = 4.562" ~ 9098' J15-1/2"BOTPBRASSY~ ~ 9-5/8" X 5-1/2" BOT 3-H PKR 12 9129' S-1/2" X 4-1/2" XO, IS = 3.958" } 9189~ H4-1/2" OTIS XN NIP, ID = 3.725" 9189~ 4-1/2" PXN PLUG (12/18/07) 9201~ 4-1/2"BOTSHFAROUTSUB 9202' 4-1/2" WLEG, ID = 3.958" 9182' E1.MD TT LOGGm 06/15/82 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-~ PERFORATION SUII~AARY R~ LOG: BHCS ON O6/07/82 ANGLEATTOP PERF: 13 @ 9460' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9460-9480 C 09/16/91 3-3/8" 4 9566-9586 C 11/07/82 3-3/8" 4 9592-9622 C 11/07/82 3-3/8" 4 9632-9658 C 11 /07/82 3-3/8" 4 9662-9672 C 11 /07/82 3-3/8" 4 9678-9688 C 11/07/82 3-3/8" 4 9692-9710 C 11 /07/82 3-3/8" 4 9726-9743 C 11 /07/82 3-3l8" 4 9755-9770 C 09/16/91 PBTD ~ 9924, 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 996T TD 9975' 9897' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/12/82 ORIGINAL COM PLETION 03/16/O6 COIWPA WANfft SAFEf`( NOTE (02/24/O6) 01/03/01 SIS-SLT CONVERTm TO CANVAS 12/18/07 TFA/PJC SET PXN PLUG 01/30/01 SIS-LG REVISION 10/27/01 RN/TP CORRECTIONS 05/24/05 EZUPJC SAFEfY WAIVER FISH - DA 27' X 3-1 /2" PERF GUN W/CCL 8~ DECBYTRALIZ6~S; LOST 06/12/82 PRUDHOE BAY UNff WElL: 13-22 PERMff No: 182-0770 API No: 50-029-20749-00 SEC 14, TION, R14E 2466.33 FEL 2341.15 FNL BP 6caloration (Alaskal TREF =' GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXEISON KB. ELEV = 84' BF. E1EV = ? KOP = 3000' Max Angle = 32 @ 6500' Datum MD = 9574' Datum ND = 8800' SS 5-1/2", 17#, L-80, TGII -2,350~ I7", 26#, L-80, BTGM ~ 120' 2,00~~ 5-1/2" "X" NIP, ID = 4.562" 13-3/8" CSG, 72#, L-80, ID = 12.347" 2520~ ~ $~ggg' 4-1l2" HES 9Cr X-Nip, ID=3.812" 9,000' 7" x 4-1/2" BOT S-3 Packer 4-1/2" 12.6#, L-80, TGII -~ 3~(~' ~ 9,034' 4-1!2" HES 9Cr X-Nip. ID=3 812" Minimum ID = 3.725" @ 9189' 4-1/2" OTIS XN NIPPLE OF 4-1/2" TBG-PC TOP OF 7" LNR 9155' - 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 9202' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~--~ 9455~ PERFORATION SUMMARY REF LOG: BHCS ON 06/07/82 ANGLEAT TOP PERF: 13 @ 9460' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9460-9480 C 09/16/91 3-3/8" 4 9566-9586 C 11/07/82 3-3/S" 4 9592-9622 C 11 /07/82 3-3/S" 4 9632-9658 C 11 /07/82 3-3/8" 4 9662-9672 C 11 /07/82 3-3l8" 4 9678-9688 C 11 /07/82 3-3/8" 4 9692-9710 C 11/07/82 3-3/8" 4 9726-9743 C 11/07/82 3-3/8" 4 9755-9770 C 09/16/91 ~~ I-I 9924' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I TD I ~2 ~$ 9-5/8" X 5-1/2" BOT 3-H PKR 9129~ 5-1/2" X 4-1/2" XO, IS = 3.958" M 9189~ 4-1/2" OTIS XN NIP, ID = 3.725" 9202' 4-1/2" WLEG, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS O6/12/82 ORIGINALCOMPLETION 03/16/06 CONVPA WAIVERSAFETYNOTE(02/24/06) 01l03/01 SIS-SLT CANVERTm TO CANVAS 12/18/07 TFA/PJC SET PXN PLUG 01/30/01 SIS-LG REVISION 10/27/01 RN/TP CARRECTIONS 05/24/05 EZUPJC SAFEfY WANER I FISH - DA 27' X 3-1 /2" PERF GUN W/CCL I & DECEIVTRALIZERS; LOST 06/12/82 PRUDHOE BAY UNff WELL: 13-22 PERMff No: 182-0770 API No: 50-029-20749-00 SEC 14, TION, R14E 2466.33 FEL 2341.15 FNL BP Exploration (Alaska) • 13 -~ ~ SAFEfY NOTES: '"'PROD CSG LEAK OPERATING LIMITS: MAX IAP = 500 PSI; Proposed RWO MAX OAP = 1000 PSI (02/24/O6 WAIV ER)'** • ~ Page 1 of 1 Schwartz, Guy L (DOA) From: Bjork, David (Northern Solutions) [David.Bjork@bp.com] Sent: Wednesday, September 30, 2009 3:03 PM To: Schwartz, Guy L (DOA) Cc: Reem, David C; Hubble, Terrie L; Stewman, Sondra D Subject: 13-22 Workover (PTD 182-077) Guy, Due to wellbore construction issues during the workover we are requesting a variance to set the new production packer more than 200ft away from the injection zone. The new completion will be ~460' MD (445' ND) away from the upper most injection interval at 9,460'. Regards, Dave 9/30I2009 ~ . Page 1 of 3 Schwartz, Guy L (DOA) From: Bjork, David (Northern Solutions) [David.Bjork@bp.com] Sent: Tuesday, September 29, 2009 9:42 AM To: Schwartz, Guy L (DOA) Subject: RE: 13-22 Workover (PTD 182-Q77} Attachments: A-31ai AOGCC Scope of Work.ZlP; A-31A Appr Sundry, 03-25-09.ZIP Guy, Unfortunately there is no place to put an RBP, in 04-02a the bottom of the scab liner was stung into an old drilling liner {full bore access below the scab). In 13-22 we will be stinging the scab liner into the old completion. The 13- 22 methadology will laok very similar to A-31 a. i am stifl checking on the feasibility of rigging up with a four RAM stack. Regards, Dave From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, September 23, 2009 4:34 PM To: Bjork, David (Northern Solutions) Subject: RE: 13-22 Workover (PTD 182-077) Dave, I saw a similar well in DS4-02A workover plan that will have two barriers ..... RBP and composite plug. Is that an easier option?? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Bjork, David (Northern Solutions) [mailto:David.Bjork@bp.com) Sent: Tuesday, September 22, 2009 10:15 AM To: Schwartz, Guy L (DOA) Subject: RE: 13-22 Workover (PTD 182-077) / N-15 workover (PTD 1$1-079) Let me see if we can fit a four ram stack on this well. It is a an old Gray GEN II wellhead system, they can be rather tall. Otherwise we would have to install 7" RAMs, run the liner, somehow hang it off and change back to VBR's. From: 5chwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, September 22, 2009 9:21 AM To: Bjork, David (Northern Solutions) Subject: RE: 13-22 Workover (PTD 182-077) / N-15 workover (PTD 181-079) Dave, N-15: I was refe~ring to KWF only for N-15. The procedure wasn't clear as to what reservoir BHP is and that SW woufd 9/30/2009 ~ . Page 2 of 3 be KWF. (Can be back caiculated from the MASP of course) barriers 1) KWF and 2) BOP rams. This operation wouid have the two required 13-22 : I have also thought about well control for 13-22 scab liner run a bit more. I am going to reqaire a set of 7"casing rams. The length of liner (almost 7000') is too much to be run without the second mechanical barrier. Couid you send a revised procedure that specifies this. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) . _ __ _ _ _ From: Bjork, David (Northern Solutions) (mailto:David.Bjork@bp.com] Sentc Monday, September 21, 2009 4:22 PM To: Schwartz, Guy L (DOA) Subject: RE: 13-22 Workover (PTD 182-077) The 2-7/8" x 5" VBRs will cover the 3-1/2" liner and workstring on N-15. _ __ _ _ . _ From: Schwariz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, Septemt~r 21, 2009 4:18 PM To: Bjork, David (Northern Solutions) Subject: RE: 13-22 Workover (PTD 182-077) Dave, You may have to do the same for N-15. Just clarify BHP and KWF here also. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Bjork, pavid (Northern Solutions) [mailto:David.Bjork@bp.comj Sent: Monday, September 21, 2009 4:05 PM To: Schwartz, Guy L (DOA) Cc: Reem, David C; Hubble, Terrie L Subject: RE: 13-22 Workover (PTD 182-077} Guy, Attached is the revised "scope of work" for 13-22 RWO. I have clarified step 4. to include kill weight fluid and one tested mechanical barrier. In step 1. we will fully circulate the well to seawater. The BHP is 3,290 psi at 8,800 ND. Please let me know if you have any questions or comments. Regards, Dave 9/30/2009 ~ Page 3 of 3 ~ _ From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, September 21, 2009 3:09 PM To: Bjork, David (Northern Solutions) Subject: 13-22 Workover (PTD 182-077) Dave, I am reviewing 13-22 workover sundry submitted last week. I have concerns about not changing the BOP rams while running the 7" scab tiner. That leaves us only one barrier. Can you contact me to discuss other options. (email or phpne is fine ) Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cel~) 9/30/2009 13-22 (PTD#1820770) Internal W~er Cancellation -UNDER EVALUATION Page 1 of 1 Re James B DOA 9J~ ~ ) From: Lau, John, Jack [IaujjO@BP.com) ''7~~ ~Z,I 12~~ 7 Sent: Tuesday, December 04, 2007 3:04 PM ~'~ 1 To: NSU, ADW Wel{ Integrity Engineer; Rossberg, R Steven; NSU, ADW Weil Operations Supervisor; Engel, Harry R; GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3); GPB, Optimization Engr; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW WI Tech; Hughes, Andrea; Holt, Ryan P (ASRC); Lau, John, Jack Subject: 13-22 (PTD#1820770) Internal Waiver Cancellation -UNDER EVALUATION Attachments: 13-22. pdf All- An internal waiver was issued for a production casing leak on well 13-22 (PTD#1820770) on 02/24106. This well was shut '~ in on 12/02/07 following a failed liquid no flow test on the inner annulus indicating its capacity to flow to surface: Under WI System Policy this well no longer is in compliance with its waiver criteria. The well has been reclassified as Under Evaluation and he internal waiver has been cancelled. A fetter cancelling the AA will be sent out shortly. The plan forward is: 1. S: Set TTP @ 9189' MD '-~ A wellbore schematic has been attached for reference. «13-22, pdf» Please call with any questions. Thank you, .lack I..:a~i (for ~'~.n~~a I3~e) ~~~"ell lntc:.grl.ty° l~<r~git~ee;r oL'fice (907) ti>~}_5>2`~ lrarn~c~nv X2378 pager (90'7j F~`~9-~10()~1923 ~J~~ ~"~ ~ ~c'_~ ~'~e1z:-jam- ~ t~~~.~~~ ~,t~~~l~ D ~ C ~ ~ 2007 12/17/2007 TREE = GRAY GEIJ 2 INELLHEAD= GRAY ACTUATOR = AXEi_St1N . KB. ELEV = 84' SF. ELEV = ~ KOP = Max Angle = 3404' 32 `~ 8500' Datum CviD = 9574" Datum TV D = 8840' SS 13-318" C5G; 72#, L-80, ID = 12.347" MlCtitT1UCC1 ~®= x.725®' C~ 9189' -~1~~~ ~T~S XN ~ppp~~ 5-1J2° TSG-PC, 17#, L-80, .4232 b(tf, ID = 4.892" 9129' TOP OF 4-1 }2" TSG-F'C --9128` TOP ©F 7° LNR I-I 91 f 4-112" TSG-PC, 12.6#, L-8d, .4152 t~pf, ID = 3.958°' ~ 9-5x'8°' CSG, 47#, L-8d, ID = 8.681°'--~55 ___ PERFORATION SUMP~tftRY REF LOG: Si~CS ON 06147/82 ANGLE A7 TOP PERF: 13 L 9460' Note: Refar to Productinir DB for historical r?erf r?ata SIZE SPF WTERVAL OpnlSgz DATE 3-3;8"' 4 9460-9480 O 0911u.191 3-318" 4 9566-9586 O 11107182 3-318" 4 9592-9622 O 11;07182 3-3;8" 4 9632-9658 O 11107!82 3-318°' 4 9&62-9672 O 11107!82 3-3l8" 4 9678-9688 O 11(07182 3-3!8"' 4 9692-9710 O 11107;82 3-318" 4 9726-9743 O 11 }07!82 3-318" 4 9755-9770 (? 09116191 FSTD 9924' 7" LNR, 29#, L-8d, .0371 bgf, IQ = fi.184" 9867" TD 9975° SAFETY NOTES: **`PROD C5G LEAi~. OPERATING LiMiTS: MAX iAp = 500 pSi; MAX qAP =1000 pSi (02}24}06 YVAiV ER)*~* [ 5-112'° HES RMQ SSSV-NEP, IQ = 4.562" ~ 9498' 5-1/2" SOT PSR ASSY 9117' 9-518" X 5-1i2" SOT 3-Fi €"rCR 9129'~1 ~ 5-1'2" X 4-1i2" XQ 9189` ~-{ 4-1?2" OTIS XN N1P: iD = 3.725" 9241' --~4-112" BOT SHEAROUT SUB 9242` 4-1,''2^ WLEG 91$2' ELMD TT LOGGED 06r'15~8`1~ 9897' "~ FISi-I - DA 27` x 3-1x'2° r'E9aF GUN W(CCL & DECENTRALiZERS; LC3ST d6i'12182 DATE REV ICY C(3iv1MENTS DATE REV SY COMMENTS 06}12}82 ORiGiNAL CgMpLETigN 43116106 COhtiPAG WAIVEr2SAFE7Y NOTE(02F24i06) 41/03/01 SIS-SLT CO4VVERTEB TO CANVAS 01x30;01 StS-LG REVISION 14127'01 RN;TP CORRECTIONS 05124}05 EZLlPJC SAFETY 'v~'ANER MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg íO I J P.I. Supervisor Kerr <ß X'¡iJ7 DATE: Monday, August 27, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-22 PRUDHOE BAY UNIT 13-22 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 13-22 API Well Number: 50-029-20749-00-00 Inspector Name: Jeff Jones Insp Num: mitJCr070826164839 Permit Number: 182-077-0 Inspection Date: 8/25/2007 Rei Insp N um: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-22 Type Inj. N TVD 8441 ./ IA 60 60 60 60 P.T. L ð.lV /IV TypeTest ::SYl Test psi 211 0.25 OA 0 1520 1430 1390 Interval REQVAR P/F P ./ Tubing 20 20 20 20 Notes: MIT OA for variance. Å:-¥O 4-c , Oð~- a./I,i'\.U.--L U:P¡OA b-¡.e. CJ..I.X' ì)< 1:A 5CANNED SEP 1 0 2007 Monday, August 27, 2007 Page 1 of I MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg Ð(" J . P.I. Supervisor t-~7 "J l/,O"7 DATE: Monday, January 29, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-22 PRUDHOE BAY UNIT 13-22 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv...JB/Z- Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT 13-22 Insp Num: mitCS070119100539 ReI Insp Num API Well Number 50-029-20749-00-00 Permit Number: 182-077-0 Inspector Name: Chuck Scheve Inspection Date: 111912007 Packer Depth Well 13·22 Inj. N 8440 P.T. 1820770 SPT Test 2110 Interval REQVAR nf_____ P -....,........--- '-'-",'- Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 0 0 0 0 0 0 2400 2340 Notes MIT tubing performed as required by variance. ~J-{) 4C.OÛ¥ - AY\I\AAi JI\;Þro,A..' ,) ¡\A.V\-"1"" ~~~ SCANNED FEB 0 7 2007 Monday, January 29, 2007 Page J of 1 Jim and Bob, Attached are the missing MIT forms questioned in your email. 1. MITs that appeared past due: 12-33 (PTD 1890100) MITIA performed on 04/17/0S PSI-Ol (PTD 20214S0) MITIA performed on 11/10/03 Z-33A (PTD 1890050) MITIA OS/09/03 12-30 (PTD 1881420) MITIA 12/04/04 2. £;lITs done: MITOA 07/29/06 MITOA 08/26/06 Please let me know if you need further information. Thank you, Þ.ndrea. s Well Integrity Coordinator Office: (907) 659-S102 Pager: (907) 659-5100 x1154 -----Origina.l Message----- From: James Regg Sent: Thursday, January 11, 2007 1:17 To: NSU, ADW Well Integrity Engineer Subject: Missing MITs We have completed a review of the MITs due during (he past quarter (October - December 2006) and due in Ja.nuary 2007. Several lists below: 1. MITs that appear to be past due *PBU 12-33* (PTD 1890100); MIT due 10/20/2006; status ?SI-01* (PTD 2021450); MIT due 11/2/2006; status - (PTD 189(050); MIT due 10/19/2006; status - ecting 2. MITs done based on ector lI1t - injecting *?BU ecting *PBU Z-33A* ty report) no Commission record of the test: *PBU 12 23* (PTD 1840580); annual MITOÞ.. done 7/29/2006 *PBTJ 13-22* (PTD 182 77 ); annua.l MITOA done 8/26/20 6 Please comple~e MITs and provide miss reports January 31, 2 07. 3. MITs d08 d~r~~; January 2 7 according to our data: *MPU C-36* (?TD 198 01 ); due 1/17/2007; status - i ect *rvIPU D 92* (PTD 98193 ; due 1/17/2 7; st.atus - ece r~g *l.V1PU F--95* (PTD 1981 9 ); due l/17/2 ; st3.tus - 2,::::= lEg lD wel~s approacDlng MT7 anniversary dace; it is acceptable 4. ¡ of2 I 16/2007935 Al'vI RECEIVED 01/23/06 Schlurnberger JAN 2 4 Z006 ~Cit&Gaseoos,~ An<:hcr"c::ge NO. 3668 Alaska Data & Consulting Services 2525 Garnbell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne PI. e 0 og eSCrlp1l0n ae o or D-10 10913021 LDL 06/02/05 1 Z-24 11183454 LDL 12/29/05 1 DS 13-22 IM~01' 10987560 INJECTION PROFILE 01/05/06 1 G-11A (REDO) 11084277 RST -SIGMA 07/12105 1 W-17A 10987549 USIT-PDCL 09/20/05 1 02-178 10928646 MCNL 09/13/05 1 1 MPS-10A 11076475 SCMT 10/17/05 1 W-17A 10913044 US IT 09/03/05 1 WII J b# L D . t' D t BL CI CD e e BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 "'e 1.. \¡..~~~It;;¡r, ð~~¡)~{S.;or,,<' L~ CI' Alaska Data & Consulting Services 2525 Garnbell Street, Suite 400 Anchorage, AK 99503-2838 ATIN &'~ "''''",,"y. - 1:íOQ1 r) Date Delivered: MEMORANDUM State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor '~d{¿ '({Ccfu) { DATE: Wednesday, November 09,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORA nON (ALASKA) lNC 13-22 PRUDHOE BA Y UNIT 13-22 Src: Inspector ~-- û 1 / \Cb Reviewed By: P.I. Suprv ..J"3.e- Comm FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 13-22 Insp Num: mitCS051 105084236 Rei Insp N urn API Well Number 50-029-20749-00-00 Permit Number: 182-077-0 Inspector Name: Chuck Scheve Inspection Date: 1114/2005 W~II . 13-22 IType Inj. ! w '-p~~-1820770_ liypeTest I - _lntervaJ. .REQV ~_.._.P/F Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I TVD __L=o -Tl, I~_ r - -60-'ï 60 -- ~·o-~_~__. 60 I -----. r----== I Testp~L__ ~~__ .~~~_ ~6~-t---!~--r 117~0.. I 116?_ 1___.._ P Tubing, 450 I 450 450 450 I --------......__.________.__.1 _ I _ . ___.____.__.__.___..--L--__.__.__ Notes Annual MIT OA for compliance with AA. ~CANNEt:' ~~O\J 1 1 2D05 Wednesday, November 09, 2005 Page I of I 13-22 (PTD #1820770) Production Casing Leak Waiver ) ) S~~~èC(:.tPi2?KPT.D#l82??70} l'rr~~C~01i Çasill~ I.êâl{.1;V~.ver..·.i;. ... ... ..··.i... .........;. ........i;.··....·.·...· IrI1~m:· N~T;T,.J\II\V.Well :rnt~~ri~y ~l1~itle¢r'!..<lN"~Ui¥O YVW~gIp:t~grity}3n~~µy~r(illB~.qOl11~ :Q!ªte.r]\1oti,3qMå)'20QS·.l$:1?:.49·-08QP·· rE ¡äì \CfJ~J ð11 Jim and Winton, Attached is a production casing leak waiver for GPB well 13-22. MITOA, MIT-T, and LNFT-IA all passed. Please call if you have any questions. Rob Mielke Well Integrity Engineer, BP Exploration, (Alaska) Inc. Office: 1-907 -659-5525 Pager: 1-907-659-5100 #1923 robert.mielke@bp.com «13-22 PC Leak 05-24-05.ZIP» 13-22 PC Leak Content-Description: 13-22 PC Leak 05-24-05.ZIP Content-Type: applicationlx-zip-compressed Content-Encoding: base64 SÇJ~,NNED ~JUN ?~ t~p 2005 1 of 1 6/6/2005 9:57 AM ) ~. ~ N/tJt';~·e ,o;fJlllø¡fI.r@(¡IW~~f .1( WELL: t3:-~~ I':"~"'~:''''~ ~. "f$~~ f'(P$l W~J~t,lnl~øtØ" IqJ~~Uøn Qªta.:·11L231Ô4: faiSOC) aWpE>@ :9tØpsÎ. Þrê$.$(jrøs: FIQ)VJng $1 Typing 11ðØ psi. 0+ pSi 'J;)n~rAoQu.lus. too þ$1 :O+Ø$i, Ft... EASaN ~OftN()'lcG.····..·i&.: ", ',', ','''',,'', '""",' ". ,.,' .',,'.' ". '" .. .. "> ,',,,,. :PreduølignCasln:gL.e;a.k TUBING X IA COMMUNICATION? ... MI1":TW:.$s:sed to $(),ÖO¡jpSi-1!1!3/04. YES fAX OA COMMUNICATION? ~, Mlm;;QA, Pa$$ßdtø30OQ p$I-1tI241Ö4. I,A X FORMATION COMMUNICATION? yeS YES X)t. .. L.NFf"IAPa$$$d"121ØaLQ4¡ .. Ú~.akR'atø:¡ntø,:thøførr'Aatiôh' is. Etägþm: '@¿·ijOQ'Þ§Î"··11114/Q,4,. IMÞO.ATANTcaNSIDERATIONS.IÇOMM~NT$: ) Ðl'tE: Outer AnnplÜ$ 9PP p,$¡ ö psi NO xx \ ... ..J ~' *: Q5-!.~~ ·?~~~Øl$ 91' PrQ(eQtibn~(ecornpeterit tûbing andtne.sutface casihghas been tesr~cj]ø. ªt!lت$.1~~·,tim~$th.EF()per.ati;i:\g prðssure¡Umlf¡..' . ·~·.AøaGø i.ssu.edAdmlo $trative Approval dated 05/05/05 allowing continued wat~r'¡I1JeQtjQrronly~ . ..', ' . NO., xx ,'J,,' ~ NO PLAN OF ACTION:· . .:.,'. ;'". A,., ~~~JMí~"'fr~m.lji~Wª "jr'.~Q$tb" pre~~pprø\ledby,théWéll$:Ctøûþ ~radthøØpØJi,~¡q",~ Mªnª$~~. · Arløw Þ\IílI: JIiJéétiô:h. ·Mønit~~.~~IÎ.h~ªdpr~~$U·~~$ánd Iqgdany~ ~.. $UÞl11i~ :~"n1~o~hIY røpÞrtQf i)'1jøctiørt ràte :andWHif?'s to the ÄOGCC. -Pøtføtrn t~ø JqlløWiljg w:ål\tør øø.mþIJào.cé Iéstiqg~ ·AnnLlålL;NrT~J:Ä, ·J\nnllaIOlr~bÅ. · Mlt;';Tsvsry i2 yê~r'$. ·lmmedia.teIY$hut~in ,the wøH ªnCJ hØtlfy,th~AQ~9C uþQrt é\Oytnèasurable change!., weir OA pressure. jJ~~2;j:):r»f;:;:~~elu~~pr~ JJlsrnDurlon: . DS tPad Operator DS I Pad Engineer .. . ; " Operating UmJts .·.,~~X.IAP·.=ï$OQP!1 Max'·Q41?= "QºQ Þ$J .:~.. ... ...., í ~, 1_. ;" "'(1 .. . '"f: . s~u~or' Date S-27-0) Date .= • ~----. '' ~ , - ~ ~I I i i ~, . J , ~ ~ ~ ALASSA OIL .~D GAS COll•ISER'PATIO.I~T COMD'IISSIOlY May 5, 2005 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. ~ '~~'~~ Q ~~~'~ P.O. Box 196612 Anchorage, AK 99519-6612 • ~l FRANK H. MURKOW5KI, GOVERNOR 1 , 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alo y~ ob(~ RE: PBU 13-22 (PTD 182-077) Request for Administrative Approval Dear Mr. Rossberg: Per Rule 9 of Area Injection Order ("AIO") 004C.000, the Alaska Oil and Gas Conserva- tion Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU 13-22. The Commission further finds that, based upon reported results of BPXA's diag- nostic procedures, PBU 13-22 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in PBU 13-22 is condi- tioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXA shall perform a yearly MIT-OA to 1.2 times the maximum anticipated well pressure; 4. BPXA shall perform aMIT-T every two years to 1.2 times the maximum antici- pated well pressure; 5. BPXA shall limit the well's IA operating pressure to 500 psi; Mr. Steve Rossberg ~ • May ~, 2005 Page 2 of 2 6. BPXA shall immediately shut in the well and notify the AOGCC if there is any indication of a change in the well's mechanical condition; and 7. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection. 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 consid- ered 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 app a1 a C~i emission decision to Superior Court unless rehearing has been requested. N ~~~~,~ Cath P. Foerster, Commissioner Dan T. Seamount, Jr. Commissioner MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg. 'Kt6[za z. (2-4 {oS' P.I. Supervisor ( DATE: Monday, January 03, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-22 PRUDHOE BAY UNIT 13-22 Src: Inspector \ <=69-" ù1 ï FROM: Jeff Jones Petroleum Inspector Well Name: PRUDHOE BAY UNIT 13-22 Insp Num: mitJJ041223161726 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20749-00-00 Permit Number: 182-077-0 Reviewed By: P.I. Suprv -::Jß2-. Comm Inspector Name: Jeff Jones Inspection Date: 12/23/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-22 ¡Type Inj. P TVD 8440 IA 0 0 0 0 P.T. 1820770 TypeTest SPT Test psi 2110 OA 0 0 0 0 Interval OTHER P/F P Tubing 310 3000 2930 2900 Notes: MIT-tubing: tubing tail plug set at 9164' MD. This well failed a MITrA (6.3 gpm LLR) on 11/14/04.2 BBLS 50/50 methanol pumped. 1 well house inspection; no exceptions. SCf\NNEC' MÞ\R 1 0\ 2.005 Monday, January 03, 2005 Page 1 of 1 ) TREE = GRA Y GEN 2 WELLHEAD = GRA Y 'Äi:::tÜÄ ;-ÓR~' "'ÄXEL'SO'N' Ks. aè/=' "" ,.. '84' 'BF~" ECEV' ~' '''7'' 'kÖp';;;"'" "'" " ""3ÒOO' . ....~. .... ......".. ....... . ..... . . . ~ ... .., ...n.. ...... . .~x ,~~,~.I~,:: ., ,~~,~L65,~o.: Datum MO = 9574' Datum TVO = 8800' SS 113-318" CSG, 72#, L-80, 10 = 12.347" l-i 2520' Minimum 10 = 3.725" @ 9189' 4-1/2" OTIS XN NIP PLE I 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" 1-1 9129' TOPOF4-1/2"TBG-FC 1--1 9129' 1 TOP OF 7" LNR 1-1 9155' 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 9202' 1 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 9455' ----.41 PERFO RA llON S UMI\AA RY REF LOG: BHCS ON 06/07/82 ANGLEA TTOP PffiF: 13 @ 9460' Note: Refer to Production œ for historical perf data SIZE SFT INTERVAL Opn/Sqz DATE 3-3/8" 4 9460-9480 0 09/16/91 3-3/8" 4 9566-9586 0 11/07/82 3-3/8" 4 9592-9622 0 11/07/82 3-3/8" 4 9632-9658 0 11/07/82 3-3/8" 4 9662-9672 0 11/07/82 3-3/8" 4 9678-9688 0 11/07/82 3-3/8" 4 9692-9710 0 11/07/82 3-3/8" 4 9726-9743 0 11/07/82 3-3/8" 4 9755-9770 0 09/16/91 I FBTD 1-1 9924' 17" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" H 996T ,--=rõ'l-1 9975' DATE 06112/82 01/03/01 01/30101 10/27/01 COMMENTS ORJGINA.L COMR..E1l0N SS-SL T CONVERTED TO CANV AS SIS-LG REVISION RN/TP CORRECllONS OA TE REV BY REV BY ~ 13-22 ) I SAFETY NOTES: ~."...:,r':II)1 ~ 2084' 1-t5-1/2" HES RMQSSSV-NIP, 10=4.562" 1 ~ L J 9098' 1-15-1/2" BOT FBRASSY 1 9117' 1-i9-5/8" X 5-112" BOT 3-H PKR 1 :g z \ / 9129' l-f 5-1 12" X4-1/2"XO 1 ff1! Ej¡ . 9189' 1--14-1/2" OTIS XN NIP, 10 = 3.725" 1 I ~I 9201' 1-14-1/2" BOT SHEAROUTSLB 1 ~ I 9202' 1-14-1/2" WLEGI 1 9182' I-fELMOTTLOGGE006/15/82 1 .. I I :r: -, 9897' 1- RSH - DA 27' X 3-1/2" PERF GUN W ICCL & OECENTRAllZERS; LOST 06/12/82 II COMMENTS PRUOHOEBAY UNIT WELL: 13-22 PffiMT I\b: 182-0770 AR I\b: 50-029-20749-00 SEC 14, TION, R14E 2466.33 FEL 2341.15 FNL BP Exp loratio n (Alas ka) RE: PBU 13-22 ) rtáIB2--077 ) ~~ ,J/?0fM Subject: RE: PBU 13-22 Fr()m: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Fri, 26 Nov 2004 14:16:29 -0900 To": James Regg <jim_regg@admin.state.ak.us>". .. CC: Winton GAubert <wintol1_aubert@acbnin.state.ak.us>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.conl>, "NSU, ADW WL & Completion. Suvervisortl <NSUADWWL&CompletionSupervisor@BP.com>, "Reeves, Donald F" <ReevesDf@BP.com>, tlGerik~ BobG (PRA)""<GerikBG@BP.com>, "Varble, Doug A" "" <VarbleDA@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>~ ''NSU, ADW Well Integrity " Engineer" <NSUADWWeIlIntegrityEngineer@BP.com> . : " Hi Jim. 13-22 is scheduled to have a TTP set in the few days. We've been delayed due to high winds shutting down crane related operations. A set of AOGCC witnessed MIT's will then be scheduled. Assuming testing goes okay, the well will remain SI with the TTP until the admin approval is processed. \ ~.....f7~ Let me know if you have any other questions. Joe 1-907-659-5102 -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Friday, November 26, 2004 10:39 AM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: PBU 13-22 Joe - What is the timing for completion of diagnostics and submittal of either corrective action plan or admin approval request for PBU 13-22? Jim Regg AOGCC SCANNED¡ NOV 2, 9 2004 1 of 1 11/26/20042:29 PM RE: Review of Wells wIFailed MITs - 13-22,03-36, NK-38, P2-34 Subject: RE: Review of Wells wIFailed MITs - 13-22,03-36, NK-38, P2-34 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Da:te: Wed, 27 Oct 2004 19:51 :35 -0800 TC);JamesRegg<.iim_r~gg@adinin.state~ak.us> . ..":. .' '. ".'. . ::"" .'" C~: Winton G. Aubert <wiritö~ aubert@admin.stäte~ak.us>,nNSU,'ADW:W elllntegrityEngineern:'. <l\íSUADWW enhitegrity~ngin~er@B;p:.com> '. . ...:.." '. . .' . '. . , . . . . .' . .' '~~';..'. .~.!.'. ,,' ,h(~. i'.'i~-;J.'...l,'/7"'.'.., ¡;P>W:~..ÇVi"l' Hi Jim, Here are updates to three of the wells requested. I am still looking into P2-34 but wanted to respond with the information I have at this time so that these reviews can be closed out. 13-22 failed an MITIA on 7/21/04 while the well was shut-in and on a vacuum. The plan has been to repair a gate valve, put the well on injection, and repeat the MITIA with the well on injection. The repair work has been completed and this well is on the schedule for an MITIA this week. The AOGCC inspector will be contacted to witness the test if possible. 03-36 failed an MITIA and passed a MIT-T on 8/2/04. An leak detection log confirmed a production casing leak at 8230' md on 8/11/04. Plans are to submit a request for Administrative Approval once M-38 AA has been approved to include any additional information required for the AA. NK-38 was not added to the monthly injection report given the plan is to workover the well instead of apply for Administrative Approval. The injection valve was opened on 9/19/04 to freeze protect the tubing and flowline for the winter. Please let me know if you have any additional questions. I will follow-up with P2-34 within the next few days. Thank you, Anna Dube -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Tuesday, October 26, 2004 4:57 PM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: Review of Wells w/Failed MITs We just completed a quarterly review of wells with MITs that failed and have identified 4 that need some clarification regarding status: 1) *PBU 13-22*; failed MIT 7/21/04; SI after MIT and well was added to monthly injector report; our database shows 3 days injection in September (26,996 bbls water); what is the status of request for administrative approval? [According to September Monthly Injector Report, tbg integrity was to be restored prior to placing on injection, and MIT was planned for 9/23/04; nor record of either] 2) *PBU 03-3é*; failed MIT 8/2/04; well was added to monthly injector report; our database shows injecti~n in August (9 days; 2,080 bbl water) and September (5,379 bbl water); what is the status of request for administrative approval? 3) *PBU NK-38*; failed MIT 7/12/04; well has not been added to monthly injector report; data provided to Commission indicates 32 bbls water injected (1 day) during September; what is status of~his well and fOllow-up to failed MIT? . 4) *PBU P2-34*; MIT 7/13/04; the Commmission carries this as an incomplete MIT (thus, requirements of 2 ~ar testing for monobore. injectors per AOqCC policy have hot been satified); MIT is incomplete because only the upper 6,400 ft of the well (perfs at 13,000 ft) has been evaluated for mechanical integrity; it is also un~lear if the well carries a waiver fr~m 20 AA~ 25.412 (packer within 200 ft of perfs) ; this well should be added to the monthly injector list. ""Î~ a c::> .;:"....1 .~ '- '-~ '-- UJ .~ 2: 'f' ::3 /' 10f2 SCANNED '.> NOV n 2 2004 10/28/20048:00 AM RE: Review of Wells wIFailed MITs - 13-22,03-36, NK-38, P2-34 20f2 I'd appreciate an update of the 4 wells so we can close out our review. Jim Regg AOGCC 10/28/20048:00 AM \Vell 13-22 (PTD 18~O770) Failed MlTtA Subject: We1113-22 (PTD 1820770) Failed MITIA From: "NSU, ADW WeB Integrity Engineer" <NSUADWWeIlIntegrityEngineer@BP.com> Date: Thu, 22 Jul 2004 09:50:41 -0800 To: "AOGCC - Jinl Regg (E-nlail)" <jim_regg@admin.state.ak.us>, "AOGCC John Spaulding (E-mail)" <jo~spaulding@admin.state.ak.us>, "AOGCC - Winton Aubert (E-mail)" <winton_aubert@admin.state.ak.us>, "AOGCC - Jeff Jones (E-mail)" <jeffjones@admin.state.ak.us> cc: "GPB, FS3 TL" <GPBFS3TL@BP.com>, "GPB, FS3 DS Ops Lead" <GPBFS3DSOpsLead@BP.com>, "NSU, ADW Well Operations Supervisor" <NSU ADWW ellOperationsSupervisor@BP .con1>, "Luedke-Chan, Beverly (PRA) " <LuedkeB@BP .com> ð ~\ ~e1.'l f\C1 l[1 Hello all. Well 13-22 (PTD 1820770) failed an MITIA on 7/21/04. The IA was pressured from 0 to 2500 psi and consistently lost -1000 psi/IS minutes. TIO plots 8how a 1000 psi tubing/IA differential, indicating the tubing has integricy. Note the well had been recently 51 due to problems ac FS3. Plan is to repeat the MITIA with the well on injection. The MITIA is currently scheduled for 9/23. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 6S9 - 5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, xl154 Email: N~~Ul\DV.J\"],=.lll nt'::";F 1 t ;:I::n'jl nr;::er,:i~hp. ':"::1m 1 of I 7/23:2004 1:.26 PIVI STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ( d \"' 7 71104 Email toWinton_Aubert@admm.state.akus.Bob_Fleckenstem@admlnstate.akus.Jim_Regg@admin.state.ak.us "'("11 OPERA TOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay 1 PBU/ OS 13 07/21/04 Joe Anders Well 13-25 P.T.D. 1820910 Notes: Packer Depth TVD 8,389' Tubing Test psi 2,09; Casing Type Inj. Type test N P Well 13-22 Type Inj. N TVD 8,440' Tubing P T.D. 1820770 Type test P Test psi 2,110 Casing Notes: MITIA Failed. Well was recently 51, will repeat the MITIA once POI. Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Test Details: TYPE II'JJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj r J = r~ot Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 Pretest Initial 15 Min. 30 Min. VAC VAC VAC VAC Interval 20 2,500 2,460 2,460 P/F 4 P VAC VAC VAC VAC Interval 4 40 2,500 1 ,400 900 P/F F Interval P/F Interval P/F Interval P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe In notes) 2004-0721_MIT _PBU_13-25.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Dan Seamount, Commissioner ~/~,,/'~"~ Blair Wondzell, P. I. Supervisor FROM: Jeff J o n es ~"~--~--/~'-~'~ SUBJECT: P etroleu m {/! n s pedto r DATE: July 12, 2000 Mechanical Integrity Tests BPX / PBU DS 13-22 PTt~ DS 13-24 PTD 182-065 DS 13-25 PTD 182-091 July 10, 2000' I traveled to BPX's Prudhoe Bay Unit DS 13 to witness the 4- year Mechanical Integrity Tests on wells #22, #24 and #25. The AOGCC test report form is attached for reference. The pretest casing and tubing pressures were observed for 30 minutes on each well with no pressure change. The standard annulus pressure test was then conducted with all three wells passing the 30-minute test. These wells should be suitable for continued injection. SUMMARY: I witnessed the successful MIT's on BPX's PBU DS 13-22, 24, 25. MIT's per[ormed on three wells, no failures. ~c~o c~ [ Attachments' MIT PBU DS 13-22,24,25 7-10-00 JJ cc; .NON-CONFIDENTIAL MIT PBU DS 13-22,24,25 7-12-00 JJ.doc sTATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: BP ExplOration ................ PT'D'~"i'~2'~Y7 / ! Ioiese~ We.#:13-22 / ~ I ~ I sW 8,409 11,830 FIELD I UNIT I PAD: Prudhoe Bay / PBU / DS 13 DATE: 7/10/00 9-5/8"/47#/L80 15-1/2'1 2,1o2 2,100 2,100 2,500 2,1oo 2,495 2,100 2,480 COMMENTS: 4-year MIT Well #: 13-24 P NaCI COMMENTS: 4-year MIT 8,438 9,706 g-5/8"/ 47# / L80 Well #: 13-25 P COMMENTS: 4-year MIT Diesel 8,389. NaCl 8,575 g:5/8"/47# / L80 PTD: Well #: COMMENTS: PTD: - " 2,110 270 2,500 2,480 2,460 5-1/2" 2,097 60 2,520 2,490 2,490 I I I I II Well #: COMMENTS: II TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 0.00 0.00 0.00 0.00 WELL TEST: Initial 4 - Year X Workover Other Distribution: orig - Well File c - Operator c - Database c - Trip Rpt File c - Inspector OPERATOR REP SIGNATURE: , AOGCC REP SIGNATURE: MIT PBU DS 13-22,24,25 7-10-00 J J1 .xls Jeff Jones (Rev 9/23/99) STATE OF ALASKA ALASKA( .... . AND GAS CONSERVATION Cqr /IiSSi{~iR ! ~ REPORT bF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Olher 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory StralJgraphic Service X 4. Location of well at surface 2874' FNL, 81' FEL, Sec. 14, T10N, ,14E, UM RECEIVED At top of productive interval 2345' FNL, 2725' FWL, Sec. 13, TION, R14E, UM At effective depth OCT I 2 !992 Alaska 0il & Gas Cons. Commission At total depth Anchorage 2343' FNL, 2813' FWL, Sec. 13, T10N, R14E, UM 6. Datum of elevation(DF or KB) 84' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-22i 9. Permit number/approval number 82-77 10. APl number 50 - 029-20749 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9975 feet 9276 feet Plugs(measured) Fill @ 9825' MD (4/14/92) Effective depth: measured 9825 feet true vertical 9129 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 2202# Poleset 79' 79' Sudace 2436' 13-3/8" 2411 sx Fondu & 400 sx PFC 2520' 2520' Production 9371' 9-5/8" 500 sx CI G, 300 sx PFC 9455' 8768' Liner 812' 7" 325 SX CIG 9967' 9268' Perforation depth: measured 9460-9480'; 9566-9586'; 9592-9622'; 9632-9658'; 9662-9672'; 9678-9688'; 9692-9710'; 9726-9743'; 9755-9770' true vertical 8773-8792'; 8876-8896'; 8902-8931'; 8941-8966'; 8970-8980'; 8986-8995'; 8999-9017' 9033-9049'; 9061-9075' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9129' MD, 4-1/2", 12.6~, L-80, PCT tail @ 9202' MD 'Packers and SSSV (type and measured depth) BOT 3-H packer @ 9117' MD; Otis RQY SSSV @ 2084' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 245O9 31118 Tubing Pressure 1461 1393 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ..~.~C(4AU&,,.,~ /~aK4..~ Form 10-~l~4~ev 06/15/8~" Title Sr. Area Operations Engineer Date /_.O//'7 ~'~ SUBMIT IN DUPLICATE 904/12 MGC cc: SW, JWP 13-22i DESCRIPTION OF WORK COMPLETED NITRIFIED FILL CLEANOUT & ACID PERFORATION WASH 4/9/92: RIH & tagged top of fill at 9826' MD. 4/13/92: MIRU & PT equipment to 4000 psi. RIH w/CT & performed a Nitrified Fill Cleanout down to 9826' MD, and reciprocated a Perforation Acid Wash across the intervals at: 9460 - 9480' MD (Sag) 9566 - 9586' MD (Z4) 9592 - 9622' MD (Z4) 9632 - 9658' MD (Z4) 9662 - 9672' MD (Z4) 9678 - 9688' MD (Z4) 9692 - 9710' MD (Z4) 9726 - 9743' MD (Z4) 9755 - 9770' MD (Z4) Ref. Log: BHCS 6/7/82. Jetted 10 bbls Xylene, followed by 2 bbls Meth Water, followed by 37 bbls 2# XCD Gel, followed by Shutdown for 30 minutes. Resumed pumping 300 - 2500 scfm Nitrogen w/2# XCD Gel, to circulate fill from the wellbore down to 9826' MD. Circulated gel w/Nitrogen until attaining clean returns, & surged well periodically to unseat any fill remaining in the perforations prior to Shutdown. Resumed reciprocating across the perforations with 4 bbls 2% NH4Cl Water, followed by 50 bbls 7.5% HCl w/15% Xylene, followed by 5 bbls 2% NH4C! Water, followed by 23 bbls Slickwater, followed by 14 bbls Meth Water, followed by Shutdown for one hour soak. Resumed pumping Nitrogen & 36 bbls Slickwater, and surged acid back from the perforations four times. Resumed pumping 54 bbls 7.5% HCl w/15% Xylene across the Perforations, followed by 5 bbls 2% NH4Cl Water, followed by 40 bbls Slickwater, followed by Shutdown POH w/CT & flushed w/Meth Water. Surged well three times. Rigged down. 4/14/92: RIH & tagged top of fill at 9825' MD. Returned well to produced water injection & obtained a valid injection rate. F ECE VED OCT 'J 2 1992 OiJ .& Gas Cons, Oommissio~ Anchorage /7 ARCO Alask~ Inc. P.O.Box 100360 Anchorage. Alaska 99510 DATE: 6-19-92 REFERENCE: 2-33 ¢'/ 2-35¢/.'-'/*7 4..35 ¢/--- ~?~"'/~°~r 9-30ST 9-32 ,~ ¢'*-'/~' ? 9-43 11.5 ~ / .-./ ~'~' ARCO CASED HOLE FINALS 5-12-92 5-21-92 5-15-92 5-12-92 5-12-92 5-17-92 5-11-92 5-16-92 5-15-92 5-25-92 Jewelry GR-Collar Prod Profile Prod Profile Jewelry Prod Profile Prod Profile PITS PITS/Flowmeter Prod Profile Prod Profile Prod Profile Prod Profile Prod Profile Gas Lift InJ Profile InJ Profile InJ Profile CCL/GR/Junk Basket Run 1, ii" Camco l~_m 1. g' Camco Ih_l_- 1, [~' C~_mco Run 1. g' Camco ~_m 1, g' Camco Run 1, 2'&N' Camco Run 1. g' Camco R,_m 1, g' Camco l~_~_n 1. g' Camco l~_m 1, g' C~_mco Run 1, g' C~_mco Run 1. g' C~_mco Run 1, ~' Camco Run 1. ~' Camco Run 1, :~'&g' Camco Run 1, [~' C~__meo Run 1. g' Camco Run 1, ~' C~_mco RUn 3, ~' Camco · Please sign and return the attached copy as receipt of data.", . RECEIVED BY ~ Have A Nice Day! Sonya Wallace. AT0-1529 APPRovED_~~~_ · Trans# 9212~Z ........ # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL * The correct APl# for 9-30ST is 50-029-21411-00. # PtHLLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO RECEIVED AUG 1 o 199 Alasks Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-24-92 REFERENCE: ARCO CASED HOT.~- FINALS Camco Camco 2 7)- ~"4~ 12-29-91 Prod Profile Run 1.5" // ~ . , 12-29-91 Temp survey & Tag Run Run~l, 2" ~~~ ? ~ ~/ 12-29-91 InJ Profile Run 1.5" t_ ~e. ~' 12-28-91 Perf Breakdown/Temp/Spinner Run 1.5" ~Lo~j-. #/ 12-23-91 Perf Breakdown Run 1, 5" -~ ~ _ .. 1-5-92 Leak Detect Run 1, 5" ~3 J/~l?v 12-31-91 Prod Profile Run 1.5" 91 InJ Profile Run 1, 5" /~r~-~ z.- ~ 2 1~--27-91 ~nj Profae ~m 1, 5" ~ ~Z[~6~2 &5" 1-3-92 PITS ~ 1, 5" ~z~3c~J-13] 12-30-91 Prod Profile/Gas Lift Run 1.2"&5" ~ ~ Leak Detect Run 1.2"&5" ~.~ )~~t~~ ~/ //? ~z zo v12.26.91 Leak Detect Run 1, 2"&5' Please ~ and return the attached c.o~y as receipt of data. RECEIVED BY____~~~~/~ I ~ _l~ve A Nice Day! ~ Sonya Wallace AP PR OV ED_~ ¥ ~ ATO-1529 Trans# 92016 ] Ca,nco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco # CENTRAL FILES # CHEVRON D&M ~ # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO RECEIVED FEB 0 3 7992 A/aska Oil ii ~as C~r~s. Co~r~i~ .. 1. Operations performed: STATE OF ALASKA ~ ALASK.A(~ ' AND GAS CONSERVATION C~~' ,,IlSSION REPORT uF SUNDRY WELL OPERATIi I I. r_ , ,, . . . Stimulate X Plugging Perforate X- '' t.~ ! IV ~ ~. .~ Alter casing ~ Repair well 2. Name of Operator Operation shutdown Pull tubing ~ ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2874' FNL, 81' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 2345' FNL, 2725' FWL, Sec. 13, T10N, R14E, UM At effective depth 5. T~:~e of Well Development ~ Explorato~ Stra~graph~: Service .X RECEIVED NOV 5 1991 Alaska 0ii & Gas Cons. C0mm'tssiO~ Anchorage At total depth 2343' FNL, 2813' FWL, Sec. 13, T10N, R14E, UM Other 6. Datum of elevation(DF or KB) 84 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-22 9. Permit number/approval number 82-77/91-270 10. APl number 50 - 029-20749 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9975 feet Plugs(measured) 9276 feet Effective depth: measured 9924 feet true vertical 9226 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 2202 # Poleset 79' 79' Surface 2436' 13-3/8" 2411 sx Fondu & 400 sx PF "C" 2520' 2520' Production 9371' 9-5/8" 500 sx Cl "G", 300 sx PF "C" 9455' 8768' Liner 812' 7" 325 sx CI "G" 9967' 9268' Perforation depth: measured 9460-9480'; 9566-9586'; 9592-9622'; 9632-9658'; 9662-9672'; 9678-9688'; 9692-9710'; 9726-9743'; 9755-9770' true vertical 8773-8792'; 8876-8896'; 8902-8931'; 8941-8966'; 8970-8980'; 8986-8995'; 8999-9017; 9033-9049'; 9061-9075' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9129' MD, 4-1/2", 12.6~, L-80, PCT tail @ 9202' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 9117' MD; Otis RQY SSSV @2084' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaoe Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 15997 16078 Tubing Pressure 1432 1434 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. F7orm 10-404 Rev 06/15/88 6/5 BHL cc: SW, JWP Title Sr. Area Operations Engineer SUBMIT IN DUPLICATE 13-22i ( DESCRIPTION OF WORK COMPLETED CHEMICAL FRAC TREATMENT OF Z4 & SAG/Z4 ADD PERFORATIONS 9/4/91: RIH & lagged bottom at 9847' MD. 918/91: A Chem Frac Stimulation was performed as follows: MIRU CT & PT equipment to 5000 psi. Pickled tubing & liner by bullheading 48 bbls of 15% HCl w/10% Xylene @ 5 bpm. Displaced acid into formation with 1% KCI freshwater, and dropped 200 ball sealers for diversion, at half barrel intervals. Began treatment of perforation intervals, located at: 9566 - 9586' MD (Z4) 9592 - 9622' MD (Z4) 9632 - 9658' MD (Z4) 9662 - 9672' MD (Z4) 9678 - 9688' MD (Z4) 9692 - 9710' MD (Z4) 9726 - 9743' MD (Z4) Ref. Log: BHCS 6/7/82. Pumped first stage at 5 bpm: a) 100 bbls 1% Surfactant/Scouring solution, w/10% Xylene, followed by b) 25 bbls 1% KCl Freshwater spacer, followed by c) 100 bbls 2% Hydrogen Peroxide, followed by d) 25 bbls 1% KCl Freshwater spacer, followed by e) 100 bbls 6% HCl, w/1000 scf nitrogen & foaming agent. Continued pumping diversion stage at 2 bpm: f) 30 bbls 1% KCl freshwater w/foaming agent @ 0.5 gpm & 6000 scfm nitrogen. Continued pumping second stage at 10 bpm: g) 100 bbls 1% Surfactant/Scouring solution, w/10% Xylene, followed by h) 25 bbls 1% KCI Freshwater spacer, followed by i) 100 bbls 2% Hydrogen Peroxide, followed by j) 25 bbls 1% KCl Freshwater spacer, followed by k) 100 bbls 6% HCI, w/1000 scf nitrogen & 1% foaming agent. Continued pumping diversion stage at 2 bpm: I) 30 bbls 1% KCl freshwater w/foaming agent @ 0.5 gpm & 6000 scfm nitrogen. Continued pumping third stage at 15 bpm: m) 100 bbls 1% Surfactant/Scouring solution, w/10% Xylene, followed by n) 25 bbls 1% KCI Freshwater spacer, followed by o) 110 bbls 2% Hydrogen Peroxide, followed by p) 25 bbls 1% KCI Freshwater spacer, followed by q) 119 bbls 6% HCl, followed by r) 250 bbls 1% KCI Freshwater displacement. Surged well to unseat balls. Shutdown. Rigged down. 9/16/91: Added perforations: 9460 - 9480' MD (Sag) 9755 - 9770' MD (Z4) Ref. Log: BHCS 6/7/82. Placed well on water injej~.C E IV E D NOV 2 § 1991 Alaska 0il & Gas Cons. Commission Anchorage Returned well to produced water injection & obtained a valid injection rate. F'. 0. Ii-: 0 X i 0 C, 36,":.;, ANCHOF:A(;E, ALASKA ""-"":..- r _: i a... D~TE' i e-25-9i ARCO CAZED HOLF FINAL_3' 9-6-9i INJ F'ROFiLE 8-26-9i PROD F'ROF.[ LE :-';-'~-F-,'i '[N.i F'ROF/GR/,rFZM,"~,~ 9-ii-9i INJ F'ROFLrLE °- i,. ..'-'- ° t, IN.i_ ,r-:' R 0 F T L E ':i.: ..... ~:~ - 9 i r~" '-,=. .... ,'_: ~-" P l':.: 0 F: L E 8--28-9i LEAK i;,ETE.'CQ'- . 8-;5t-9t LEAK DETECT ':2-t :2-9i F'F:O0 F'ROFII_E 9-9-9i F'ROD PROFILE 9 --- i 2 "" 9 i L. E A K i;' E'f' E E: T 9-t 4-9't PROD F'F..'OFILE 8-i 8-9i GR/CCL. 9-:.'3-'.7i GAY LEAl< £:,i£TECT c.:, ... ,::, ,.:; ._ 9 i ! c:' A ¢,." T) E "- e:' :",-,- .*..-- ~...L.. ,~'. ... :::.'ON'fA WALL. AC:E: A i::' F:' F.',' 0 V 1::: RUN RUN i, 5' CAMCO RUN i, 5· CAMCO F.: U N t , _, ~' ' r;. i':', t~ C CT, i;: U t...! i: 5" tJ A ~'"i ('-:t'J RUN i, _,"':' CRMCF~_ RUN t, ~l CAMr30 RUN i, .~. ='" CAHCO RUN i, 5' CAMCO ~ ;: (. J ~'l .~ i , ..:.=' · & i ,'-'; "._. C. A iff CCi RUN i , 5" CAMCO RUN t, _,~-' " CAMCO RUt..! i, i · CAf'iC:O F:..,,..~ !-;'.i i uF DA'iA,. D !S'TR ]: BUI']:CiN C E N T R A L. F :,r. i... E,? -,. C H ii: V'R 0 N -,- EX-I"FN$10N E.×P'LOK'~ ;' tUN E X X 0 N "5 '~' i::: ::. "" ' i F'~ i". i r.,l--lJ...t..l ] h,..,,.: $-- H (] B' l L AMr':HORA~';r-' '~ ' KA DATE' ~ ¢,-i ~-9i i-...' E F E F.: E N C E ' ARCO CA£ED HOLE FiNAL£ ]~.ot~.o-o 6'-'ii 8-~-9~ GR/CCL CORRELATION RUN ~-oo~' 0 7-4 °-':'i-°i, ~ ,COLLAR LOG cUI;'. , MERLA PACKER RUN -e' i~ ~-o~3-o r--~ -~9-9~ F'ERF BREAK DOWN RUN ~, 5-" [g-O;flS-o 7-23 6-2t-9t F'ERF RUN 7~- oo3x- o o-~. 7 8-~-ot, LEAK-Q/XPINNER/TEMP RUN 24 ~g. o~a~- o ~ ~- 9-6-9t F'ERF RUN ~ oo'7~- oi S-'~9 9-i 6-9t PERF RUN ~- o o ~' o i 4- ¢ ¢-~8-°i D~N RUN i 5" HAVE A NICE DAY! t' / AiaskaOil&Gas. C~missi0n $ONYA WALLACE APPROVE ATO-~ 529 'T'RAN$~- 9~- HL£' HL£' HL~,' fILS' HLZ.: DISTRIBUTION CENTRAL FILES' * ~ PHILLIPS CHEVRON PB WELL FILES D & M R & D EXTENSION EXF'LORATION ~ ~ BPX EXXON '- ~ STATE OF ALASKA MARATHON TEXACO MOBIL STATE OF ALASKA ALASKA'~(,~. AND GAS CONSERVATION C~'~ :ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown ~ Alter casing Repair well Plugging Change approved program Pull tubing Variance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Ser~ce Re-enter suspended well Time extension Stimulate Perforate X 4. Location of well at surface 2874' FNL, 81' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 2345' FNL, 2725' FWL, Sec. 13, T10N, R14E, UM At effective depth At total depth 2343' FNL, 2813' FWL, Sec. 13, T10N, R14E, UM 12. Present well condition summary Total depth: measured true vertical 9975 feet Plugs(measured) 9276 feet Other feet 6. Datum of elevation(DF or KB) 84 RKB 7. Unit or Property x Prudhoe Bay Unit 8. Well number 13-22 9. Permit number 82-77 10. APl number 50 - 029-20749 11. Field/Pool r,, Er~.B~,y._O'&Poo~ :L:I: I V I:U SEP 6 1991 Alaska 0il & Gas Cons. Commissten Anchorage Measured depth 79' 2520' 9455' 9967' Effective depth: measured 9924 feet true vertical 9226 feet Junk(measured) Casing Length Size Cemented True vertical depth Conductor 79' 20" 2202# Poleset 79' Surface 2436' 13-3/8" 2411 sx Fondu & 400 sx PF 'C' 2520' Production 9371' 9-5/8" 500 sx Cl 'G' 7 300 sx PF 'C' 8768' Liner 812' 7" 325 sx CI 'G' 9268' Perforation depth: measured 9566-9586'; 9592-9622'; 9632-9658'; 9662-9672'; 9678-9688'; 9692-9710'; 9726-9743' true vertical 8876-8896'; 8902-8931'; 8941-8966'; 8970-8980'; 8986-8995'; 8999-9017'; 9033-9049' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9129' MD; 4-1/2", 12.6g, L-80, PCT tail @ 9202' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 9117' MD; Otis RQY SSSV @ 2084' MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation 15. Status of well classification as: September 1991 16. If proposal was verbally approved Oil Gas Suspended Name of approver Date approved Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed FOR COMMISSION U~l:: ONLy Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Title Sr. Area Operations Engineer Form 10-403 Rev 06/15/88 c: SW ORIGINAL SIGNED BY Date I Approva, No.?/_~,~ Approved Copy Returned Commissioner Date SUBMIT IN TRIPLICATE WELL 13-22 Ivishak Perforating Procedure 1. MIRU ELU and test lubricator. Perforate the zone 4 interval from 9755'-9770'md (Ref. BHCS 6/7/82) at 4 SPF. 4. Return well to injection. RECEIV£D SEP 6 1991 Alaska Oil a Gas Cons. Comm'~ss'~en Anchorage 4 2 CO]LED 1U811~ UNIT 1. ~)00 PSI 7" W[LLH~ CONNECTOR rLAJ~G[ 2.~K)O0 PSI 4 1/16" PIPE: IL~S 3.~ PSi .4 1/r flYDIV~IC: SLIPS 4.~K)C)O PSI 4 1/6" ~ RAMS 5.SO00 PSI 4 1/6" BLIND RAIDS 6.SO00 PSI 4 1/16" STUFFIHG BOX .]REL].,NE BOP, E,.OUIPHENT 1. ~)000 PSI 7" W[LLHr..AD C::ONN£CIOR :2.~)OO0 PSI WIR[LIN[ RAIDS (V,I, R IABL[ SIZ 3. ~)000 PSI 4 1/6" L UBRICATC)R 4. 50C)C)PSI 4 1/6" FLOW TUBE: STATE OF ALASKA ALASK/( 'LAND GAS CONSERVATION C~' MISSION APPLICAtiON FOR SUNDRY APPROVALS 1. Type of Request: Alter casing Repair well Plugging -- Change approved program Pull tubing Variance 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2874' FNL, 81' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 2345' FNL, 2725' FWL, Sec. 13, T10N, R14E, UM At effective depth At total depth 2343' FNL, 2813' FWL, Sec. 13, T10N, R14E, UM 5. Type of Well F. xpiorata7 Stratigraphic Serum RECEIVED 5 0 1991 Alaska Oil & Gas Cons. Corniness'ton Anchorage Re-enter suspended well -- ,,~O ~ Time extension Stimulate Perforate X Other 6. Datum of elevation(DF or KB) 84 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-22 9. Permit number 82-77 10. APl number 50 - 029-20749 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9975 feet Plugs(measured) true vertical 9276 feet Effective depth: measured 9924 feet trUe vertical 9226 feet Junk(measured) Casing Length Size Cemented Conductor 79' 20" 2202# Poleset Sudace 2436' 13-3/8" 2411 sx Fondu & 400 sx PF 'C' Production 9371' 9-5/8" 500 sx Cl 'G' 7 300 sx PF 'C' Liner 812' 7" 325 sx CI 'G' Measured depth True vertical depth 79' 79' 2520' 2520' 9455' 8768' 9967' 9268' Perforation depth: measured 9566-9586'; 9592-9622'; 9632-9658'; 9662-9672'; 9678-9688'; 9692-9710'; 9726-9743' true vertical 8876-8896'; 8902-8931'; 8941-8966'; 8970-8980'; 8986-8995'; 8999-9017'; 9033-9O49' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9129' MD; 4-1/2", 12.6g, L-80, PCT tail @ 9202' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 9117' MD; Otis RQY SSSV @ 2084' MD 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch X 14. Estimated date for commencing operation 15. Status of well classification as: September 1991 16. If proposal was verbally approved Oil .__ Gas Suspended Name of approver Date approved Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Date FOR COMMISSION U~l:: ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. Plug integrity BOP Test Location clearance I Mechanical Integrity Test , Subsequent form required 10- z~°/+' --6 0o~3¥ ORIGINAL SIGNED BY Approved by order of the Commissioner LONNIE C, SMITH C Form 10-403 Rev 06/15/88 C: SW SUBMIT IN TRIPLICATE WELL 13-22 SAG RIVER PERFORATING PROCEDURE . 2~ MIRU ELU and test lubricator. Perforate the Sag River interval 9460'-9480'md (Ref. BHCS 6/7/82) at 4 SPF. e 4, Return well to injection. RECEIVED AU G ~ 0 lg91 Alaska Oil & Gas Cons. CommiSsien Anchorage 6 5 4 3 2 I i COILED TUBING UNIT BOP Ei)tJ 1 PI, IE Nt 1. 5000 PS1 ?" V/[LLH~ CONN£CTOR FLANGE 2. 5000 PSi 4 1/16" PIPE RAMS 3. 5000 PS1 4 1/6" I'IYD~IC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAU$ $, 5000 PS1 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16'* STUFFING BOX 3 2 RECEIVED AU G ~ 0 1991 1 tska Oil & Gas Cons. C;ommissior' Anchorage #IRELINE BOP, EOUIPHENT 1. 5000 PSI ?" WELLHEAD CONNECTOR rLA~ 2. 5000 PSI WIRELIN[ RAJAS (VARIABLE SiZE 3. 5000 PSI 4 1/6" LUBRICATOR- 4. 5000 PSI 4 1/6" FLOW TUB[ 'PACK-OFF STATE OF ALASKA ALASKA( AND GAS CONSERVATION C~ .ISSION APPLICA, ,ON FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ~ Operation shutdown ~ Re-enter suspended well ~ Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Variance Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 9951O-O36O 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 2874' FNL, 81' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 2345' FNL, 2725' FWL, Sec. 13, T10N, R14E, UM At effective depth At total depth 2343' FNL, 2813' FWL, Sec. 13, T10N, R14E, UM 6. Datum of elevation(DF or KB) 84 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-22 9. Permit number 82-77 10. APl number 50 - 029-20749 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9975 feet Plugs(measured)l true vertical 9276 feet Effective depth: measured 9924 feet J~U~I~t tg t true vertical 9226 feet Junk(measured) Casing Length Size Cemented ~ ~~'~ depth True vertical depth Conductor 79' 20" 2202# Poleset 79, 79' Sudace 2436' 13-3/8" 2411 sx Fondu & 400 sx PF 'C' 2520' 2520' Production 9371' 9-5/8" 500 sx CI 'G',. 300 sx PF 'C' 9455' 8768' Liner 812' 7" 325 sx CI 'G' 9967' 9268' Perforation depth: · measured 9566-9586'; 9592-9622'; 9632-9658'; 9662-9672'; 9678-9688'; 9692-9710'; 9726-9743' true vertical 8876-8896'; 8902-8931'; 8941-8966'; 8970-8980'; 8986-8995'; 8999-9017'; 9O33-9O49' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9129' MD; 4-1/2", 12.64t, L-80, PCT tail @ 9202' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 9117' MD; Otis RQY SSSV @ 2084' MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation September 1991 16. If proposal was verbally approved Oil __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~'' ~ Title Sr. Area Operations Engineer %,/ FOR COMMISSION U~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ORIGINAL SIGNED BY RUSSELL A. DOUG~ Approved by order of the Commissioner ADDroved C~ODv Commissioner Form 10-403 Rev 06/15/88 - iR~l~j'll~ ' ' 738BHL c: SW, JWP /- / 15. Status of well classification as: Gas Suspended Injector J Approval No. Date ~/~/~/ SUBMI'[/IN T~IP~ICATE Drill Site13-22i Zone 4 Selective Stimulation This selective stimulation is to increase injectivity into the lower portion of the Zone 4 interval. Stimulation will be accomplished as follows: 1. If needed jet out wellbore fill with slick water, and HC1/xylene. 2. Pickle wellbore with 2,100 gallons of 15% hydrochloric acid containing 10% dispersed xylene. 3. Stimulate Zone 4 interval with the following sequence: a. Divert high perm zone With ball sealers b. 4,200 gallons water with 10% xylene and 1% oil-cutting surfactant c. 4,200 gallons 2% hydrogen peroxide d. 4,200 gallons 6% hydrochloric acid e. 1,250 gallons water with foaming agent plus 100,000 SCF nitrogen for foam diversion f. Repeat b. - e. g. Repeat b. - d. i. 10,500 gallons 1% potassium chloride water to flush 4 2 COILED 'I'UBI. Nt3 UNIT BOP EglU ! PME NT 1. 5000 PSI 7" WELLHr.~ CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAUS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS S. ~d:)O0 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING; BOX H]REL]NE BOP EOUIPHENT 1. 5000 PSI ?" WELLHEAD CONNECTOR IrLANGI 2. 5000 PSI WIRELIN£ RAIDS (VARIABLE SIZE) · 1.5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF F'..(:)~ BOX i00¥8(') ¢'~ N E: I--t 0 R A G E, A L ~."-~ S' K A .- / ....* . i'. Ii" I::' E R. E 2 ..... 4 3 ""'.iii'- ?' 'i C 0 L. L. A R / F' E R F: F.: U i'-~ i: '.5:" '" ':'; "'"- 8-".:'; : " ,::,-'_ ,_ 'i i LE.,.':'.~I< DETEC".,"J:C!N i;;Ur4 ?;- t 2 2 .... ! 6 - 9 i I N J E C 'T' ]: 0 N F' F;.: U I:- I L E :., F;.: U r.,i i , 5 :' 3 - t '7 2 .... i '7 --':? i I i'J, ,J E C 'f' .1'_ 0 N F' I:;; 0 F i L E R U r,! 'i: 5 "' ..-5 -.- :?. (:);'.5 -- i i --. ? i C ¢.) L. b ¢1 ~;~ e t.J i'-~. ....,"z .... ,~..'~a., ,.,".=' .... i 4--9i COI...L..Ai;.:/F'i:::F;,'F. HUt...! 'i: :5" ':~: .... ".~: ,":', ..'!!; ..... 'i ,:::-.. (:, .JC 0 J... L.. s::l F;.'./" F:' E;.. · ..~ ......... . ....- ... .... . 4 .... i '.5 2 .-.. 2,'..:;,.-':,-,o 'i 'f' E M F:' iii; F;.'. A '1- U F;,' E I.,..' U r.4 i , :5" · -.a ... · ..... .."5 .... i 8 2 ..... i ," .... '.;,' 'l F:' F;: ri D I IC"I" I [2.1N F.F. 0 I:- ]. L E tk U f'-,t 'i ...... 8--'.24 ?-;-6.-.-?' i Ci'iL.L.,-.'tI-~/F:'EF;:F' l.,..'tJiq 'i ':~'" ...... .1, ....' 7- 23; ,.-.."') '"' i 4 .... 9 t F:' l; T;';' ",;'-'::":;"~ :3'"'2-9' 'i F"I:.I',.:I-' J;.{~',;i':: D~N/TEMF'EF;:A'I"UF~E/,¥;F:' I Ni"~I.EF;.: I.;.:Ur.4. 'i, 5:" ,::; ..... 9 ,,.'; .-) .... ..:, ..-:, .... o .~ E: 0 L. i... A I:;.: I:,..' U i',~ .. .: ..... ...'.....'.. .... , . ~ ; ...:' i 2'".'.5 3..- 'i 5..-.';? 'i C C I... K L.~ r,.! i, '.5" t :3 .... 7 '1 -. ;'..!;.... ? 'l '1' E i',i I::' E I:;.' f.'.~ T t..I F;.: IE / 2' F:' I N N E R I:;.'. U N t , 5." ,.,,-- "' "' "' ..... t 3 - t !i t .... ;2.-.-. ? 'i I N,J E C 'i' I 0 N W / G R C 0 I.,, I-,1:.. L ~-~ I .[ 0 N R U N .......... I"' F;,' ., 'f ,:s- 2.,:: t .... ,;~ - '.? t I f'-/._ E:. C, 1' I 0 N 14,,," [;. F;,' C 0 R R E L. ch 1' I 0 N LJ N. t " ~ 4-6 ".' ........ ~..- t 3....?'i LEAK DIF'i Et., I ION RUN t 6-24 ':~ .- ,:: n -. c, 4 " :', (.~..¢.~ ¢ L I I::' T ;.".;'LJ R V E Y R L.IN 'i , ")" ~":," .'... ~......t .. · I::'L. EA:'CE ;~;IGN AND F'41.":'T't..II';,'N THE"' A'I"TACHED C, OF'Y AS RECEIF'r OF"' DATA, I.-IAVIE A NICi.:: DAY! 3'HAI:i:ON WIL..3'r]N ATO-. t '.529 A F' F' R' 0 V E D ' f' I:;.: t-~ N S :'.': D I ;S"f' Fi: I BUT I ON · "' CE N'rR~.'tL FILE,S' 'Ir '"' .., I"1E'. V R [1N D &-M · ..... o ~ ·. E:;',T'EN$ ION EXF'LORP, 1'I:OiSl E"XXO~ t"t A I-( ~'~ 'i" H (J N · ,-'"' M OB I i.. ~ F:' I"11 L L I F:' ,S' F'B WELL F ]:I_ES R & D ~' BF'X · 11· '"' $'I' r-~'l L£ tiff '1"EX'CO Alasl~a Oil & Bas Cons. Bommis¢on AnchoTage A F: f'". ~'i ..... ;-.. A, i N C: .. F',. C.. = BOX i ,3,'336,3. ANCHORAGE, ALA.S'KA 995i ;3' r:, ,, .-r.:' · 2-J 4-90 REFERENCE' ARCO PRESSURE DATA i-iA ii-23-89 BHP--g']"ATiC GRADIENT CAMCO 2-8 ti-30-89 BHF ....STATIC GRADIENT CAMCO 3-7 i 2-4-89 BHP--S'TATiC ~2-RADiENT CAMCO ,S-'i'~) i i-25-89 BHP--i~'!'AT!C ~-RADIENT CAMCO 4-2J i i-24-89 BI--IP--:,:TAT!C GRADIENT CAMCO 7-5 ~27-89 BHF ..... S'i'A'F ! C (~RAD!ENT CAMCO 'i3-5 i i-24-89 BHF ....~:TATiC: GRAD]:ENT CAHCO i ~-'¢ i 2--i 6-89 BHF--~ ~ ~.~ ~ lC (;RADiENi' CAMCO ~-.:~ t i6-89 BHF ....STATIC GRADIENT CAMCO !4-i3 t2-6--89 BHP--Z'i'ATiC GRADIENT CA~CO i4-27 t2-t7-89 BHF ....5'TAT!C GRADIENT CA~CO t4-3i 12-4-89 BHP--ZTAT~C GRADIENT CAHCO t4-36 12-i6--89 BHP--$TATIC GRAD]:ENT CAMCO PL. EA,2'E ~'"rGN AND RETURN "[I'-tE A'I"T~CHF'D COPY A;.:7 I';.:ECEIF'T OF DA'i"A., RECEIVED By ~/~¢~~-- ~.:AL. LY HOF'FECI<r~:R FEB 161990 APPROVED .~.__ I'RAN3':~ 9,3~.) 6 S DISTRIBUTION CENTRAL FILES .,~'"' CHEYRON 'Ii' EXTENSION EXF'LORATION ~"" EXXON " MARATHON~ ." ...... MOBIL ' PHI LL I F':~,' PB WELL FILES R & D BPX · STATE OF AI_A5'I<A TEXACO ARCO ALASKA, INC. F'..O. BOX t0036G ANCHORAGE, ALASKA 995t DATE- 9-t8-89 REFERENCE' ARCO CASED HOLE FINALS t -7 8-23-8,° 2-4 ,0-2 -8,0 2- 4 ,0 8-24-89 3- 4 6 8-25-89 4-5 8-30-8,0 4- 49 8-29-89 4- t 9 8-30-89 6-t4 9-tG-89 7-t'0 8-~t-89 t 2-2t 8-a0-89 t~-22 8-at-8~ ~ 4-20 8-~0-8~' t4-24 8--~t --8~ ~ 4-~4 8-a0-89 t6-4 8-t a-8~ ~7-7 t 7-t t 5-1 ~-8~ PRODUCTION PROFILE LEAK DETECTION SURVEY PITS INJECTION PROFILE STATIC TEMP SURVEY STATIC TEMP SURVEY TEMP FM COLLAR LEAK DETECTION SURVEY TEMP SURVEY INJECTION PROFIL. E PRODUCTION PROFILE PRODUCTION F'ROFILE PRODUCTION PROFILE LEAK DETECTION LEAK DETECTION LEAK DETECTION RUN t, 5" RUN t, 2" RUN 4, RUN t, 5" RUN t, 2"&5" RUN ~, 2"&5" RUN t, 2" RUN 4, RUN t, RUN ~, 5" RUN t, RUN 4, RUN ~, 5" RUN t, RUN ~, RUNS RUNS PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO ATLAS CAMCO HR$ CAMCO CAMCO CAMCO CAMCO CAMCO OTIS OTIS RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-4529 CENTRAL FILES CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO ARCO Alaska, Inc. Prudhoe Bay =,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 30, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-22 Approval No. 8-453 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. SCheve DFS/3CB/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 13-22)W1-3 WELLS2/163 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-O STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Z Plugging _-- Perforate - Pull tubing Alter Casing ~ Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2874' FNL, 81' FEL, Sec. 14, TiON, R14E, UM At top of productive interval 2345' FNL, 2725' FWL, Sec. 13, T10N, R14E, UM At effective depth At total depth 2343' FNL, 2813' FWL, Sec. 13, T10N, R14E, UM 5. Datum elevation (DF or KB) 84' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 13-22 8. Approval number 8-4,53 9. APl number 50-- 029-20749 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth' measured true vertical 9975 feet 9276 feet Plugs (measured) Effective depth: measured true vertical 9924 feet 9926 feet Junk (measured) Casing Length Surface 79' Intermediate 2436' Production 9371' Liner 812' Size Cemented Measured depth 20" 2202# Poleset 79' 13-3/8" 2411 sx Fondu & 2520' 400 sx PF 'C' 9-5/8" 500 sx Cl 'G' & 9455' 300 sx PF 'C' 7" 325 sx C1 'G' 9967' ~ue Verticaldepth 79' 2520' 8768' 9268' Perforation depth: measured 9566-9586'; 9592-9622'; 9632-9658' true vertical ; 9662-9672' ; 9678-9688'; 9692-9710' ; 9726-9743' 8876-8896'; 8902-8931'; 8941-8966'; 8970-8980'; 8986-8995'; 8999-9017' Tubing (size, grade and measured depth) 5½", 17#, L-80, PCT @ 9129' MD; 4½", I2.6#, L-80, PCT tail @ 9202' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 9117' MDI Otis RqY SSSV @ 2084' MD 12, Stimulation or cement squeeze summary Intervals treated (measured) ; 9033-9049' Treatment description including volumes used and final pressure 13. R .tr. ivr' u See attached ~G ~a~ Oil & Gas Cons, I 0mm ion Representative Daily Average Production or Injection Data Prior to well Operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 0 10,000 -- 1050 Subsequent to operation 0 0 10,000 -- 500 14. Attachments 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 WELLS2/163 J. C. Braden, 263-4536 Date ~'/g'~ I Submit in Duplicate¢/ Drill Site 13-22i Selective Stimulation Procedure 7/6/88 ARCO Alaska, Inc. performed the following stimulation treatment: 1. MIRU wireline unit. Taged bottom and recorded PBTD at 9674'MD 2. Performed fill clean-out. 3. Loaded 5000 gal of 15% HCI acid and 10000 gal of 12% HCI-3% HF acid. 4. Loaded 10000 gal 2% NH4CI water containing a biocide. Si Loaded 1250 gal 2% NH4CI water gelled with 40 Ib/Mgal HEC polymer. The gelled fluid should contained biocide and a foaming agent. 6. Loaded 350 bbl seawater. 1 MIRU pump trucks and nitrogen truck. Installed a foaming aspirator (foaming tee or foaming orifice) in the injection manifold 8. Rolled all compartments before pumping fluids downhole. 9. Pumped the following fluids down the tubing: 10. 11. a. 2000 gal. b. 2500 gal. c. 5000 gal. d. 5000 gal. e. 180 bbl. f. 2500 gal. g. 5000 gal. h. 3000 gal. i. 35O bbl. 2% NH4CI water with biocide 15% HCI with additives, dispersed with 10% xylene 12% HCI-3% HF with additives, dispersed with 10% xylene 2% NH4CI water with biocide 82 Quality Foam consisting of 1250 gal of 2% NH4CI water with foaming agent, biocide and 40 Ib/Mgal HEC polymer, nitrified with 6700 SCF N2/bbl water (200 MSCF N2). 15% HCI with additives, dispersed with 10% xylene 12% HCI-3% HF with additiveS, dispersed with 10% xylene 2% NH4CI water with biocide seawater (filtered) Resumed water injection at RIR. Recorded rate and wellhead pressure. RD and released pump trucks and transports. ARCO Alaska, Inc. f~ Prudhoe BayE,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 7, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-22 Permit No. 82-77 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JCB/jp Attachment Cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 13-22)W1-3 R£¢EIVED JUN 9 1988 Alasl~ 011 & Gas Cons. Commission Anchorage WELLS2/163 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ALASK AND GAS CONSERVATION COMM ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension r~ Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate C Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, A~chorage, AZ( 99510 4. Location of well at surface 2874' ~T~, 81' FEL, Sec. 14, T10N, R14E, UN At top of productive interval 2345' FNL, 2725' ~'~L, Sec. 13, T10N, R14E, t~ At effective depth At total depth 2343' FNL, 2813' FWL, Sec. 13, TiON, R14E, UM 5. Datum elevation (DF or KB) 84 ' [~B feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 13-22 8. Permit number 82-77 9. APl number 50-- 029-20749 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 9975 true vertical 9276 Effective depth: measured 9924 true vertical 9226 Casing Length Size Surface 79 ' 20" Intermediate 2436 ' 13-3/8" Production 9371 ' 9-5/8" Liner 812 ' 7" feet feet feet feet Plugs (measured) Junk(measured) RECEIVED JUN g lg88 Cemented 2202# Poleset 2411 sx Fondu & 400 sx PF 'C' 500 sx C1 'G' & 300 sx PF 'C' 325 sx Cl 'G' Measured 79Anchorage 79' 2520' 2520' 9455' 8768' 9967' 9268' Perforation depth: measured 9566-9586'; 9592-9622'; 9632-9658'; 9662-9672'; 9678-9688'; 9692-9710'; 9726-9743' true vertical 8876-8896'; 8902-8931'; 8941-8966'; 8970-8980'; 8986-8995'; 8999-9017'; 9033-9049' Tubing (size, grade and measured depth) 5½", 17#, L-80, PCT @ 9129' MD; 4~", 12.6#, L-80, PCT tail @ 9202' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 9117' MD; Otis RQY SSSV @ 2084' MD 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation June 1988 14. If proposal was verbally'approved Name of approver Subsequent Work. tleported on Date approved 15. I hereb~ certify~t/~at 7 ~'~ goin_g is true and correct to the best °f mY kn°wledge Signed ~,~/{~r't,~4,~,_.~ Title Operations Engineer±ng Manager Date Conditions of approval Commission Use Only Notify commission so representative may witness i Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned - ,~ -. Commissioner by order of the commission Date Form 10-403 Rev 124-85 WELLS2/163 J. C. Braden, 263-4536 Submit in triplicate Drill Site 13-22i Selective Stimulation Procedure ARCO Alaska Inc., proposes to perform the following stimulation treatment: 1. MIRU wireline unit. Tag bottom and record PBTD. 2. If PBTD is above 9743'MD (bottom of perforations) then perform a FCO and load the sump with brine. Last PBTD was 9714'MD (8/7/88). 3. Load 5000 gal of 15% HCI acid and 10000 gal of 12% HCl-3% HF acid. 4. Load 10000 gal 2% NH4CI water containing one of the following biocides: B.J./Titan Dowell Halliburton XCIDE-102 at I gal/Mgal M-76 at 1 gal/Mgal BE-3 at 0.2 gal/Mgal 5. Load 1250 gal 2% NH4CI water gelled with 40 Ib/Mgal HEC polymer. The gelled fluid should contain one of the above biocides and one of the following foaming agents: B J /Titan: Dowell: Halliburton: FAW-16 at 5-10 gal/Mgal F75N at 3-5 gal/Mgal Pen-5 at 1% by volume 6. Load 350 bbl seawater. 7. Load 220 MSCF Nitrogen (200 for foaming and 20 for warm-up). 8. MIRU pump trucks and nitrogen truck. Install a foaming aspirator (foaming tee or foaming orifice) in the injection manifold 9. Roll all compartments before pumping fluid downhole. 1 0. Pump the following fluids down the tubing: 11. 12. a. 2000 gal. b. 2500 gal. c. 5000 gal. d. 5000 gal. e. 180 bbl. f. 2500 gal. g. 5000 gal. h. 3000 gal. 2% NH4CI water with biocide 15% HCI with additives, dispersed with 10% xylene 12% HCI-3% HF with additives, dispersed with 10% xylene 2% NH4Cl water with biocide 82 Quality Foam consisting of 1250 gal of 2% NH4Cl water with foaming agent, biocide and 40 Ib/Mgal HEC polymer, nitrified with 6700 SCF N2/bbl water (200 MSCF N2). 15% HCI with additives, dispersed with 10% xylene 12% HCl-3% HF with additives, dispersed with 10% xylene 2% NH4CI water with biocide i. 350 bbl. seawater (filtered) Resume water ~R. Record rate and wellhead pressure[:;{, RD and release pump trucks and transports. ,JtJ~ Alas~ 6 ,5 4 2 COILED '[IJBINi~ UNIT BOP EDu ] PHEN7 1. ~K)O0 PSI ?" WELLHEAD CONNE~OR IrLAI~G£ 2. 5000 PSI 4 1/16" PIPE RAMS 3. ~ PSI 4 1/6" HYDRAULIC SLIPS 4. ~X)O PSI 4 1/6" SHEAR RAMS 5. ~K)O0 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 1 ' IJ 2 HIRELINE BOP EOUIPHEN7 1. 5000 PSI ?" WE LLHEAD CONNEC10R £ LANGi 2. 5000 PSI WIRELIN£ RAI~S (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO Alaska, Inc. I"~O, Box 10~360 5("' ( ..... Anchorage, A i.a~'ka 99 , DAI'E' August t8, t987 REFERENCE: ARCO Cm~ed HoLe Final t''---~--. .-.~ 8-7-87 CCL/Perf. Record Run t, 5' t2-25 8-8-87 CCL/Perf. Record Run 2, 5' t2--27 8-7-87 CCL/Perf. Record Run t, 5" t3-1e 8-te-87 CCL/Perf. Record Run 2, 5" t3--22 8-t2-87 Spinner F'rofite Run t, 5' $ch ,~ch $ch ~?c h S'ch Please .sign arid return the attached copy as receip't of data. Cenfrat Fi Les Chevron F'B WeLt D & M R & I) Extension ExpLorafion ~ ~ohio E x x 0 I~ ~a~e of Marathon ~ ~ Texaco Mob i [ Fil. e~ ALaska A R C 0 A L a '.~ I-,' a, I n c ,. I::', O· Box ~ ~(:):3;60 An,:"hor age, A La:.~ka DATE' duty t4, ~987 REFERENCE' ARCO Pressure Data t3--t7 5-t-87 Surface Pressure Fa[toff Arco t3-20 5-2-87 Surface Pres_cure FaLtoff Arco t3-22 5-3-87 Surface Pressure Fattoff Arco F'l. emse ~ign and return the a'ttached copy as receipt of data, Received By ........................................................ HAYE A NICE DAY! Rosanne Peek A';'O- t 529 'T'RAN$ ~:8736t Ap p roved .................. Alaska Oil & Gas Cons, Commission Anchorage D ].,S' rRIBU'rlON C. entra[ Fi [es Ch err on · .'"' I) & M IF x t' e n.s i o n F.E x p I. o r a t i o n '"".-Ex XOl~ · "'... Mob i I. '"..-F'hi [Lips F'B I,..' ~.:.: ;. ;"; I. es '"'..- R & D · .'"' $~a~e of ALaska · "'.~ 'r e X 8 C (:) ARCO Alaska, Inc. F' 0 Box t' ~ Anchorage, Alaska 99510 I)AI'E' November i 7, i986 REFERENCE' ARCO Cased HoLe Final 2-7 8-27-86 ~;pinne¥' Survey Run t, 2' F'LopetroL ")"-- z Run ~ ~ ~. 2-t5 8-~Z 8o J;pinner ~urvey FLopetroL 2-1 8 8-' 1 -z.,_.,,o ~zl'e m p . .,eurve y R u n I , '~'~ F L o p e t r o L 3-4 8-'~'~-°z.:~ ,~, ~;p inner Eurvey/Temp . Eurvey Run t , 2'. F [ope't¥'o !. o--~.--.,~, Ep nner ~'urvey Run t, '~' FLopet¥'oL '~" F [opetro I. S-t0 ~,°-"~'~-°z,.~. ,~,~ ~pinner ~urvey (MuLti-ra~e) Run t, ~. 3-t'~.~ 8-2~-.86 ~'pinner ~urvey/Temp. ~'urvey Run t, ~'~ F'l. opeSroL ~" F Lope'~ro L 6-9 8-'t~86 Temp~ ,~urvey (F'ump in) Run t, ~ '"' "' F Lop e t' r o L 9-'.~t 8-4-86 ~p inner Run t, ~. ~2 8-6-86 PBU/~'pinner SCurvey Run t, 2" Flope'troL t ~- t 7 8 '~ '~" F L o p e 1' r o L -.~t-.86 ~'pinner ~urvey Run t, ~ t~-2G 8--2t-86 ,~pinner ~urvey Run t, 2' FLopet'roL ~-~'*~ 8-28-.86 ,~pinner S'urvey Run t, 2" F'Lopet'rok F'Lease ~ign and re'turn ~he at't'ached COPY 8.S' receip~ of dat'a. I.,:,_._.-ce i vecl By HAVE A NICE Ro~alql]e Peel< ATO-t.~.9~-'~' TRAN$ ~:867S6 DISTRIBUTION · ..~Cen'fraL Fi Les ,.J" Ch e¥1- Ex-tension ExpLoration Exxon Marathon ~ Mob i L F'hi ll. ips PB Well Fi les R & D .IL ~ ..,, ~;oh io · ..~.,.:?.,.,fa't:e""of A Lasl<a -'. .,,.'"' ]'e×aco ARCO Alaska, !nc F'.O. Box i Anchorage, Alaska 995t~ DATE' Augu£t 7, i986 REFERENCE' ARCO Cased Hole Final "-~3-i6 4-8-85 CoLlar log Run ~4-4-85 CCL,"'erfora$ing Rmrord Run i ~6-9 7-28-86 Spinner Fluid ID 5" ~tt-9 6-t -86 D i*'~erenT,, iai Temp Pumpin .Pun. i ~i- 2-4a i_~-t~°-°~=.~ Completion Record Run i ~-~:" ~i2-5 i2-i~-85 Perforafing Depth Con~ro~ Run 3 ~2-?a io-iTM~ ~ ~ . F'erfnra~ ~ng_ Depmh, Cont'co[ . Rut, i ~i2-i4 t~-i~-°~~ ~~,~ Perforating Depth Con,roi Run S u.~-' ~i2-i6 i2-1~-8~ Comp[e!~on Record Run ~t3-2t i2-28-85 Pe:-fora~ng Record Run i ~ ~-22 2-9-85 EF'Log Run i 5' F'[ease sign and reSur'n +.he a+.+.ached copy as receip+, of Received By HAVE A NICE DAY! Linda Hu[ce AT0-i529 Alaska Oil & G~s Cc, ns Gommtss~o~ ,~ncn~ra~e TRANS ~..m ~.~ -~t ~'--~ Cenfra.; ~i Les Chew-on D'& M Extension Exp lora+, ion Exxon Hara · ~ . ._ Phi [Lips F'B WeLL Fi ,'-es R & D S £oh ia -.- i exaco ARCO Alaska, In . Post Office Box 100360 Anchorage. Alaska 99510 Telepho.ne 907 276 1215 Date: July 24, 1985 ,~ ~ Reference: ARCO CH Finals · "-~~ 5-12-85 9-16 Spinner 7-10-85 ~-17 Spinner 7-10-85 13-22 Spinner b-26-85 13-23A Spinner 7-11-85 13- 23A spinner 6-26-~5 Run 1 5" 'DA 1 5" Otis .- 1 5" Otis 1 5" Otis 1 5" Otis 1 5" Otis Please sign as receipt of data. Received by. Pam Lambert ATO 1429C ':'J~"~ ~'~ ~ b~s Cons. Corrlrriiss/orl Anchorage Trans 223 C~ron D&M Expl. Services. Ext. Exploration Exxon Marathon Mobil Phillips PB Well Files R & D Sohio Stateof Alaska Texaco A n c h o'r' .:?~ g .~'-'., A i. a :.x k a l:: i i. e S A F:"-"-' ^ i...'.-': :ii: k a, I n c I::'~ O ~ Bc.,x 'i C,¢:)36~'.) 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'Ti:;:AN,i;'., :iI:4.(!:,'3 ~ STATE OF ALASKA ALASK~ .,gL AND GAS CONSERVATION ,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-77 3. Address 8. APINumber P.O. Box 360, Anchorage, Alaska 99510 50- 029-20749 4. Location of Well 2874' FNL, 81' FEL, Sec. 14, T10N, R14E, OM (surf) 2345' FNL, 2725' FWL, Sec. 13, T10N, R14E, UM (top producin¢ 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number ~) D.S. 13-22 2343' FNL, 2813' FWL, Sec. 13, T10N, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 84' RKB I ADL 28315 12. Check AppropriateBox Tolndicate NatureofNotice, Report, orOtherData OTHER [] NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions an Form 10-407 with a submitted Form 10-407 for each completion.) 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105,170). ARCO Alaska, Inc. has converted DS 13-22 to a Water-Alternating-Gas Injection well. Th date of first injection was 12/27/82. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Post Oltice Box 360 Anchorage. Ale 99510 Telephone 9.07'%. 563'7 June 23, 1983 Reference: Arco Cased Hole Finals D.S. 1-25-~ 3-14-83 D.$. 2-19{,/ 3-26-83 D.S. 2-21--' 3-27-83 D.S. 2-23~.. 3-25-83 D.S. 2-24t / 3-23-83 D.S. 2-25" 3-23-83 D.S. 2-262 3-24-83 D.S. 6-9 3-3-83 D.S. 6-22~" 4-29-83 D.S. 13-2A ~-~"3-1-83 D.S. 13-12~' 3-31-83 D.S. 13-22 3-20-83 D.S. 13-98~ ........ 3-17-83 D.S. 14-26 / 2-27-83 ACBL/VDL/GR/Signature PLS/Spinner PLS/PBU-Spinner PLS/PBU-Spinner PL$/Spinner PLS/Flowmeter .PLS/PBU-Spinner DDTNLL/GR - - CCL & Perf'Record ACBL/VDL/GR/Signature PLS/$pinner PL$/Temp/$pinner/Plow~eter/HP/GR GR DDTNLL/GR Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA . Run 1 5" DA Run 1 5" DA Run 2 5" DA Run 1-3 5" GO Run 1 5" DA Run 1 5" DA ' Run 1 5" DA Run 1 5" DA Run 1 5" DA e sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 385 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS ' H CARQ. L-~NE SMIT , ~ ~ !~ ~:.: ~ ~.~ . ARCO Alaska, Inc.'~t'" Post Office ~ux3' 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 11, 1983 Reference: A~co Pressure Data D.S. 1-4'.," 4-10-83 ,--T~10-83 Pressure Build-up GO Pressure Build-up Survey Report D.S. 6-20~ 4-27-83 Static Survey GO D.S. 6-21 -" 5-4-83 Static Survey Otis · D.S. 6-22~ 4-29-83 Static Survey GO D.So 6-24j 5-1-83 Static Survey GO D.S. 11-2~/ 4-23-83 4-23-83 D.S. 11-6 4-22-83 ~-22'83 D.S. 13-12 /,~-6-83 "3-30-83 Pressure Build-up GO Pressure Build-up Survey Report Pressure Build'up' GO Pressure Build-up Survey Report Pressure Build-up DA Pressure Build-up Survey Report D.S. ~i3-22 ~3-20-83 D.S. 13-26~/ 4-10-8.3 4-10-83 D.S. 15-1/ 3-25-83 /-3-25-83 D.S. 15-2/ 3-26-83 /3-26-83 (CONTINUED) NORTH GEOLOGY R&D DR I L L I'NG PHILLIPS SOHIO MARATHON CHEVRON Fall-Off Pressure Survye'DA Pressure Build=up Otis Pressure Build-up Survey Report Pressure Build-up GO Pressure ~uild-up Survey Report Pressure Build-up Camco Pressure Build=up Survey Report DISTRIBUTION EXXON MOB I L GETTY D&M STATE O,F ALASKA DALLAS CAROLINE SMITH Post O~'fice Box 360 Anchorage.~"'~ska 99510 Telephone ~ 277 5637 December 16, 1982 RE: ARCO Pressure Surveys D.S. 3-8 11-20-82 D.S. 3-13 12-3-82 D.S. 3-15 11-21-82 D.S. 6-4 12-2-82 D.S. 6-11 11-11-82 D.S. 6-12 11-11-82 D~S. 11-6 11-7-82 D.S. ll-7 .11-7-82 D.S. 13-1 10-22-82 D.S. 13-3 10-23-82 D.S. 13-5 10-29/31-82 D.S. 13-22 11-22-82 D.So 13-23A 10-12-82 D,S, 13-24 11-19-82 Static Survey Pressure Bui 1-d-up Static Survey Pressure Build-up Static Survey Static Survey Static SUrvey Static Survey Static 'Survey Static Survey Pressure Bui ld-up Static Survey Static Survey Static Survey Camco Gearhart Camco Otis Camco Dresser Camco Camco Camco Camco Camco Camco Camco Camco D.S. 17-5, 11-18-82 Static Survey Camco /~~~.'17-6 11-18-82 Static. Survey Camco Please~ sign and return the attached copy as receipt of data. Becky Benedi ct AFA - 403 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON Trans. #662 EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS Anchora§e ARCO Ala$1(a. Inc. is a Subsidiary of AtlanticRichfielaComD ~nv ARCO Alaska, Inc. ( Prudhoe BayEngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 10, 1982 C. V. "Chat" Chatterton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re: D.S. 13-19 Permit No. 81-180 D.S. 13-22 Permit No. 82-77 D.S. 13-25 Permit No. 82-91 D.S. 13-32 Permit No. 82-123 Attached are Subsequent Sundry Notices and Completion Reports for the subject wells. Due to conversion of the surface piping on these wells for injection, i.e. choke and check valve reversed from the producing configuration, the usual well tests were not obtained following perforation. These wells were unloaded briefly to tanks during perforating and were subsequently shut-in to await injection startup. Very truly yours, D. F. Scheve DFS/lmi Attachments cc' Sohio Petroleum RECEIVED DEC2 ~aska Oil & Gas Cons= Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany ALASKA AND GAS CONSERVATION CO ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL []XX OTHER [] 2. Na o..f_Op~r~tor. 7. Permit No. "~CU Alaska, Inc. 82-77 8. APl Number 3. Ad~eS~)o o Box 360, Anchorage, Alaska 99510 5o- 029-20749 4. Location of Well 2874' FNL, 81' FEL, Sec. 14, TION, R14E, UM (surf) 2345' FNL, 2725' FWL, Sec. 13, TiON, R14E, UM (top producin 2343' FNL, 2813' FWL, Sec. 13, TION, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 84' RKB I ADL 28315 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number ) g.s. 13-22 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations I-~X 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). Began perforating operation 11/18/82. RU perforating unit, pressure tested surf equipment. RIH with gun #1, shot 9691-9709' MD, 4 spf (18' Ref: CNL 6/15/82), flowed tank for clean-up, monitored rate and took shakeouts, POH - all shots fired. RIH with gun #2, shot 9725-9742' MD, 4 spf (17' Ref: CNL 6/15/82), flowed to tank. POH - all shots fired. RIh with gun #3, shot select-fire 9677-9687' MD and 9660-9670' MD, 4 spf (20' Ref: CNL 6/15/82), flowed to tank. POH - all shots fired. RIH with gun #4, shot 9640-9656' MD, 4 spf (16' Ref: CNL 6/15/82), flowed to tank. POH - all shots fired. RIH with gun #5, shot select-fire'9630-9640' MD and 9610-9620' MD, 4 spf (20' Ref: CNL 6/15/82), flowed to tank. POH - all shots fired. RIH with gun #6, shot 9590-9610' MD, 4 spf (20' Re~SLL. CNL 6/16/82), flowed to tank. POH - all shots fired. RIH with gun #7, shot<9~~584' MD, 4 spf (20' Ref: CNL 6/15/82) , flowed to tank. POH - all Shots fire .dS-~RD. Secured well 11/20/82. RECEIVED DEC2 1 !9B2 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .2~. ~~_ _~~ Title Regional Engineer The spaCe below for Commission use Conditions of Approval, if any: Oil & Gas Cons: Commission Anchorage Date ,~./,~'"'/~G'~,, - By Order of Approved by. COMMISSIONER the Commission Date ce Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate . STATE OF ALASKA ......... (~¢, . -wEL, L, ALAS/~ Lri~-AND GAS CONSERVATION ~ ..,vIISSION COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL)~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-77 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 5o- 029-20749 4. Location of well at surface 9. Unit or Lease Name 2874' FNL, 81' FEL, Sec. 14, TION, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2345' FNL, 2725' FWL, Sec. 13, TION, R14E, UM D.S. 13-22 At Total Depth 11. Field and Pool 2343' FNL, 2813' FWL, Sec. 13, TION, R14E. UM Prudhoe Bay Fi eld 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 84' RKBI ADL 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 5/25/82 6/8/82 6/16/82 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9975'MD,9276'TVD 9924'MD,9926'TVD YES'IX NO[--1Inipple @ 20~J(~MD 1750' (approx) 22. Type Electric or Other Logs Run DTL/SP/BHCS/GR, FDC/CNL/GR/Cal, HI)T, LSSL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf. 79' 36" 27f17¢/ Pnl 13-3/8' 72.0# L-80 Surf. 2520' 17~" 2411sx Fnndu & 480 ~× P~rmafrnst C 9-5/8" 47.0# L-80 & Surf 945'5' 12~" 500'~x Cla_~_~ G & 3fl()~× P¢rmafrn~t S00-95 7" 29.0 L-80 9155' 99,67' 8½" 325sx 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) Ref' BHCS 6/7/82 5½ 9202' 9129' 9566-9586' MD 9592-9622' MD 8792-8965' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9632 96'58' MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9662-9672' MD N/A 9678-9688' MD ,~19.01~2L ' 9692-9710' MD' ' , 9726-9743' MD 27. N/A PRODUCTION TEST I Date First Production ' Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO , TEST PERIOD · ' Flow Tubing Casing Pressure CALCULATED.k OIL-EEL GAS-MCF WATER:EEL OIL GRAVITY-APl (corr) Press. ' 24:HOUR RATE "~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. DEC2 1 !982 ~Jaska Oil & Gas Cons, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9560' 8870' N/A D/W Contact 9794' 9099' Base Sadlerochit Not reached 31. LIST OF ATTACHME'NTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~/~~~~~ TitleReoional Enein~r Date .,,. ._ . . INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and '24: If this well is completed for separate production from more than one interval (multiple completion), .so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Prudhoe Bajr "~gineering Post Office [ . 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer November 22, 1982 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re- D.S. 13-6 Permit No. 81-121 D.S. 13-9 Permit No. 81-158 D.S. 13-15 Permit No. 82-157 D.S. 13-16 Permit No. 82-148 D.S. 13-19 Permit No. 81-180 D.S. 13-21 Permit No. 82-53 D.S. 13-22 Permit No. 82-77 D.S. 13-23A Permit No. 82-23 D.S. 13-24 Permit No. 82-65 D.S. 13-25 Permit No. 82-91 D.S. 13-32 Permit No.-82-123 Attached are "Notice of Intention" the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TKKW/lmi Attachments cc' Sohio Petroleum Sundry Notices work proposed on RECEIVED DEC 0 8 i98Z A~ska._ Oil ,= '~ G~ Cons. Ccmmissior~ ARCO Alaska, Inc. I$ a Subsidiary of AllantlcRIchfleldCompany ALASKA ,L AND GAS CONSERVATION C vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Narr&e~o~f,~Op~r~tor 7. Permit No. ~u~iaska, Inc. 82-77 8. APl Number 3. Ad~)reS~o o Box 360, Anchorage, Alaska 99510 50- 029-20749 4. Location of Well 2874' FNL, 81' FEL, Sec. 14, TION, R14E, UM (surf) 2345' FNL, 2725' FWL, Sec. 13, TiON, R14E, UM (top producin 2343' FNL, 2813' FWL, Sec. 13, TION, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 84' RKB 6. Lease Designation and Serial No. ADL 28315 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number i) D.S. 13-22 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [~X Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc proposes to convert this well to Water-Alternating-Gas Injection service. Injection will be into the Sadlerochit; surface piping and instrumentation have been installed as necessary for injection. A downhole safety valve will remain in service in this well following the initiation of injection. A non-freezing fluid was left in all uncemented annuli within the permafrost interval. Su~s~ue~t ~, o~1~ 14- I hereb~(~rtify that t3~°~is tr~ correct to the best of mY kn°wledge- Signed ~~t~'~~.~. ~ -~ Title ,egi0nal The space below for Commission use Conditions of Approval, if any: Engineer ! ~Approved Copy Returned Approved by ~Y ~;~¥ ~' [~'~J~[[~ COMMISSIONER By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Post Office B 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 8, 1982 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: D.S. 13-22 -- Permit No. 82-77 Enclosed are the "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. ,~e~truly yours, .... F. Scheve ~gional Engineer DFS:TKKW:skh Enclosures cc: Sohio Petroleum Company ARCO Alaska, inc. is a subsidiary of AtlanticRichfieldCompany STATE Of ALASKA ALASK/~ LAND GAS CONSERVATION _q~ AMISSION SUNDRY NOTICES AND REla'ORT$ ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 360; Anchorage~ AK 99510 4. Location of Well 2874'FNL, 81'FEL, Sec. 14, TION, R14E, UM (Surf) 2345'FNL, 2725'FWL, Sec. 13, TION, R14E, UM (Top Prod) 2343'FNL, 2813'FWL, Sec. 13, TION, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 84' RKB 6. Lease Designation and Serial No. ADL 28315 7. Permit No. 82-77 8. APl Number 50- 029-20749 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-22 11. Field and Pool Prudhoe Bay Field Pr,,Hhmp Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations I'-I Altering Casing [] Stimulate [] Abandon [] Stimulation I-'1 Abandonment r~l Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10~407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for ~njectianinto ~, the Prudhoe Bay Unit. Upon perforating, the well will be flowed to a tank for cleanup and production. All wireline work Will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV.will be installed at the conclusion of the perforating and cleanup operation. Intended perforation intervals: 9566-9586'MD 9592-9622'MD 9632-9658'MD 9662-9672'MD 9678-9688'MD 9692-9710'MD 9726-9743'MD Ref: BHCS 6/82 · Signed~ Title Regional Engineer Date / ~/~~ Approval, if any: Approved by BY' LONNJE 1~. SMIT,~ COMMISSIONER Approved Copy Returned By Order o~ the Commission Date Form 10-403 Rev. 7-1-80 Submit ".Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ~ "360 Anchorage,l. aka 99510 Telephone 907 277 5637 August 10, 1982 Reference: Arco Open Hole Finals D. S. ~'.~ ~i3-22 D.S. 13-24 D.S. 13-25 6-7-82 Geodip w/listing Run 1 2" Sc 5-17-82 Geodip w/listing Run 1 2" S( 7-2-82 Geodip w/listing Run 1 2" Sc D..S. 2-24 6-5-82 BHCS Run 1 2" S¢ D.S. 2-24 6-5-82 BHCS Run 1 5" Sc D.S. 2-24 6-5-82 Density/Neutron (Raw) Run 1 5" S( D.S. 2-24 6-5-82 Density/Neutron (Poro) Run 1 5" S( D.S. 2-24 6-5-82 DIL/GR Run 1 2" D.S. 2-24 6-5-82 DIL/GR Run 1 5" ase sign and return the attached copy as receipt of data. KellY McFarland Trans. # 364 DISTRIBUTION CHEV~0N ARCO Ala$1<a, Inc. is a sul~sidiary of AtlanticRichfieidCompany ~0N~ MOBIL. GETTY D&~ GEOLOGY Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine DriVe Anchorage, Alaska 99501 (907) 279-1433 RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANT I TY DESCR I PT ION DA TED: // / Copy sent to sender YES /-/~' NO ARCO Alaska, Inc. Post Office/B,~x 360 Anchorag~ ]ska 99510 Telephone- 90.T'277 5637 July 30, 1982 Reference: Arco Open Hole Finals D.S. 13-22 6-7-82 D.S. 13-22 6-7-82 D.S. 13-22 6-7-82 D.S. 13-22 6-7-82 D.S. 13-22 6-7-82 D.S. 13-22 6-7-82 D.S. 13-22 6-7-82 D.S. 13-22 6-7-82 D.S. 13-22 6-7-82 D.S. 13-22 6-7-82 .... D. S ....... 13,~2:2,:~ 6- 7- 82 D.S. 14-22 6-6-82 D.S. 14-22 6-6-82 D.$. 14-22 6-6-82 D.S'. 14-2'2 . / 6-6-82 D.S. 14-22~/ 6-6-82 D S. 14-22 6-6-82 ~. "~4-22 ~ 6-6-82 -~ D.S. _ 18-2 7'14-82 D.S. 18-2 7-14-82 D.S. 18-2 7-14-82 D.S. 18-2 7-14-82 D.S. 18-2 D.S. 18-2 D.S. 18-2 D.S. 18-2 D.S. 18-2 FDC FDC FDC/CNL FDC/CNL DIL/$FL DIL/SFL Long Spaced Sonic BHCS .CPL/Cyberlook Hi Res. Dipmeter Fracture ID Log Hi Res. Dipmeter DIL/GR DIL/GR BHCS BHCS Density/Neutron Raw Data Density/Neutron Porosity CPL/Cyberlook Comp. Densilog/GR Comp. Densilog/GR Comp. Densilog/ Comp. Neutron/GR Comp. Densilog/ Comp. Neutron/GR 7-13-82 DIFL 7-13-82 DIFL 7-13-82. BHC Acoustilog/GR 7-13-82 BHC Acoustilog/GR 7-,!4-82 Prolog DISTRIBUTION. Run 1 2" Sch. Run 1 5" Run 1 2" Run 1 5" Run 1 2" Run 1 5" Run 1 Waveforms 2 Run 1 Waveforms 2 Run 1 5" Run 1 5" Run 1 5" Run 1 2" Run 1 · 5" Run 1 2" Run 1 5" Run 1 5" Run 1 5" Run 1 5" Run 1 2" DA Run 1 5" Run 1 2" Run 1 5" Run 1 2" Run 1 5" Run 1 2" Run 1 5" 51! . NOAT~ GEOLOGY EXXON ~ ~ C LC I V ~ 0 R&O~- MOBIL . n r, ni c cEr AUG- 1982 ' ~~ D~ A~aska OiJ & Gas Cons. Co~issk S~HI02 ' GEOLOG~ Anchorage .. ~~ON ~:~TA~ OF ~S~. C~ON ~~ Please sign and return the attached copy as receipt of data. Kelly McFarland._ ~ ~ ~~ Trans. ~ 334 " ' AR~O Alaska, Inc. is a subsidiary of AtlantlcRichflel~Company ARCO Alaska, Inc. Post Office ~( 360 Anchorage,~ ~ka 99510 Telephone 907 277 5637 July 28, 1982 Reference: ARCO OPEN HOLE FINAL LOGS D.S.13-22 6/7/82 HDT/Arrow plot clster program run 1 5" with listing D.S.13-25 7/2/82 HDT/Arrow plot clstr program run 1 5" with listing Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmitta~ # 322 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS' SOHIO~;. MARATHON CHEVRON ARCO Alaska, Inc. is a sul~sidlary of At}antlcRlchfleidCompany EXXON MOBIL GETTer D&M GEOLOGY AUG- 3 1982 Oil & Gas ~,nChora~ Comrnissiot] Post Office Box 360 Anchorage, ~ :a 99510 Telephone 905~ ~/'7 5637 July 19, 1982 Reference: ARCO CASED HOLE FINAL LOGS D.S.14-17 5/23/82 D.S.15-5 5/19/82 D.S.17-4 5/23/82 D.S.17-4 5/22/82 D.S.17-4 5/2/382 D.S.18-1 6/21/82 D.S.13-22 6/11/82 D.S.2-22 6/12/82 D.S.2-22 6/13/82 CNL Run 1 5" CNL Run 1 5" EPL Run 1 5" CCL & Perf Record Run 1 5" CCL for Gas Lift Mand. Run 1 2" Diff Temp Log Run 1 5" ACBL/VDL/GR Run 1 5" Caliper Log Run 1 5" Gamma Ray Collar Log Run 2 5" Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal f~ 278 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY ARCO Alaska, Inc./~ Post Office t.. .360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 14, 1982 Reference: ARCO CASED HOLE FINAL LOGS D. S. 13-22 DOS.13-26 D ° S. 2-24 D. S. 13-26 D. So 2-24 DoS. 12-5 D.S°12-10 D.S.12-11 6/15/82 CNL Run 1 5" 6/13/82 ACBL/VDL Run 1 5" 6/8/82 ACBL/VDL Run 1 5" 6/16/82 CNL Run 1 5" 6/14/82 CNL Run ~1 5" 6/20/82 & 6/30/82 CPL(TDT-M) 5" with computer list 6/18/82 & 6/30/82 CPL(TDT-M) 5" with computer list 6/17/82 & 6/30/82 CPL(TDT-M) 5" with computer list Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 270 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON CHEVRON ARCO Aiasxa :", '. ~s ~. ~' ~i:' :: ~:'¥ Cf A~lar~!=c,qichfieidCompan,v RECEIVED JUL 2 8 J.982 Alaska 0il & Gas Cons. Comrnissier~ Anchorage ARCO Alaska, Inc. Post Office B~r~ .50 Anchorage, Al~,sKa 99510 Telephone 907 277 5637 July 27, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton- Enclosed are completion reports and gyroscopic surveys for the following wells' DS 2-24 DS 15-6 North Prudhoe Bay St. #2 Since the information on North Prudhoe Bay St. #2 is of a confidential nature, we would appreciate it if you could store it in a secure area. If you have any questions, please call JoAnn Gruber. Sincerely, P. A, Van Dusen District Drilling Engineer PAV/JG:llm Enclosures REdE ~VE D GRU1/L5? J U L 2 8 1982 Nask. a 0il & Gas Cons. C0mmissior~ Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany '" ~,(' ? STATE OF ALASKA . ALAS~, ..JL AND GAS CONSERVATION (~' .MISSION 0 I~ I GIN A L WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILX~xX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-77 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20749 4. Location of well at surface LOCATIONS 9. Unit or Lease Name 2874' FNL, 81' FEL, Sec. 14, T10N, R14E, UP! VERIFIED Prudhoe Bay Unit At Top Producing Interval Sur~, ~ - 10. Well Number 2345' FNL, 2725' FWL, Sec. 13, T10N, R14E, UN I~.H. ~ 13-22 At Total Depth ....... 11. Field and Pool 2343' FNL, 2813' FWL, Sec. 13, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 84' RKBI ADL 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 05/25/82 06/08/82 06/16/82 N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9975'MD,9276'TVD 9924'MD, 9226'TVD YES I~l NO [] nipple @ 209~eetMD 1750' (approx) 22. Type Electric or Other Logs Run D IL/SP/BHCS/GR, FDC/CNL/GR/Cal, HDT, LSSL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT.. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2U" 91.5# H-40 Surf 79' 36" 2202 # Poleset 13-3/8" 72.0# L-80 Surf 2520' 17-1/2" 2411sx Fondu & 400 sx Peri~afrost C 9-5/8" 47.0# L-80& Surf 9455' 12-1/4" 500sx Class G & 300 sx P,,~rmafrost C S00-95 7" 29.0# L-80 9155' 9967' 8-1/2" 325sx 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) None 5-1/2" 9202 ' 9129' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED · N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED ~ OIL-BBL GAS-MCF WATER-BBL elL'GRAVITY-APl (corr) Press. 24-HOUR RATE:._ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None , ur°ge Form 10-407 Rev. 7-1-80 Submit in duplicate GRU1/WC9 CONTINUED ON REVERSE S DE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl e rochi t 9560' 8870' N/A 0/W Contact 9794' 9099' Base Sadlerochit Not reached 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 Signed Title Date --_ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), s..o state in item 16, and in item 24'show the producing interv~.ls for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23' Attached supplemental .records for this well should show the details of any multiple stage cement- 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 DS 13-22 Drilling History NU 20" Hydril & diverter. Spudded well @ 0030 hrs, 05/25/82. Drld 17-1/2" hole to 2526'. Ran 62 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2520'. Cmtd 13-3/8" csg w/2411 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 3297'. POH. Left fish (bit-XO-MDC-NBS) = 37.97' in hole. Top fish @ 2807'_+. Unable to recover. Drlg sidetrack @ 2740'. Drld to 9462'. Ran 231 jts 9-5/8" 47#/ft, L-80 & S00-95, BTC csg w/shoe @ 9455'. Cmtd 9-5/8" csg w/500 sx Class G cmt. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 9945'. Ran DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, HDT & LSSL. Cont drlg to 9975' TD (06/08/82). Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls water, 300 sx Permafrost C, & 125 bbls Arctic Pack. Ran 20 jts 7" 29#/ft, L-80 liner f/9155'-9967'. Cmtd 7" lnr w/325 sx Class G. Drld cmt to 9924' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/9050'-9899'. Ran 5-1/2" completion assy w/tail @ 9202' & pkr @ 9129'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced tbg w/diesel. Dropped ball & set pkr. Nipple for SSSV @ 2090'. Instld tree cap & tstd to 5000 psi - ok. Secured well & released rig @ 1500 hrs, 06/12/82 Gyroscopic survey ran on 06/16/82 JG-11m 07/21/82 GRU1/DHiO Eastman / 1 Whipstock l)~ A PETROLANE COMPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKAr INC. COMPANY DS 13r Well Number: 22 WELL NAME Prudhoe Bay, North Slope, Alaska LOCATION JOB NUMBER A0682G0443 TYPE OF SURVEY Gyro Multi Shot DATE 16-Jun-82 SURVEY BY Coram/Jahn OFFICE Alaska Eastman Whipstock (907) 349-4617 P. O. Box 4-1970/Anchorage, A/aska 99509-1970 July 2, 1982 ARCO ALASKA, INC. P.O. BOX 360 Anchorage, Alaska 99510 Well Number: DS 13-22 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Gyro Multi Shot Date: 16-Jun-82 Method of Computation: Radius of Curvature Surveyor: Coram/Jahn Job Number: A0682G0443 Attn: Bob Hines Dear Mr. Hines, We are enclosing the original and sixteen copies of the Gyro Multi Shot Survey run on the above mentioned well. To date, the following distribution has been accomplished: A;''i copy telecopied to E/W North Slope office for delivery to ARCO field representives. · B;'!6~,.copies delivered to drilling for in-house distribution. C2''3 copies for E/W permanent well files. We wish to take this opportunity to thank you for calling on our services and we trust that we may continue to serve your needs in the future. Sincerely, SHYAM TALWAR District Operations Manager ST/bb cc: file enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO 'A[.ASt,~A, INC, ' OS .... ' .1. ~ · W.F..I.ZL-- NO l ")'"~,. ~.. .... GMS ..................................................................................................................... :-'tr~'B'"'i*-~fi;:t ........ ........ -¢'-,0-,S82G0-4'4';.~ .............................. F'RLIDHOE BAY, NORTH SE. OPE, Af..ASKA GMS, 0-9850 MD, St..IRVEYOR! CORAM/JAHN CAMERA_ NO ** .1.,..,""'7".',.., S287 GYRO NO ~ M6°.. .,.,., 6,..~2 I~' .,"') .,-. ...5-90 DEG., A/U NO { .1..._.,6,,:., 156'':-) FORESIGH"r.; N .1.0 W DATE RUN~ 16-JU~.~-82 VERTICAl... SECTTON CAI..CULA A FS"7~OOqNE QO~WW4NY RECOR[i OF SURVEY RADIUS OF CURVATURE METHOD DS .1.3... WEL. L. ,NO: 22 F'F,'UDHOE BAY: NORTH C:Ui"i~k'U'i R'~ i ur4 GMS JOB' NO: AO682G0443 T.T. HE DATE S L.' 0 F' E ,- -A I':'A S K A 1'~"~"2 ~:":'38 ............. 02 ='3 U TRUE M E A S l.I R E D'- D R I F T .....KfR I F T .......... C'O E! RS'E-'U ER~FY.'C'~E ..... UER'T"I'C'A E' .......... -S UBS E A ........... R'"--'E'-C--'T--A-7,-'~-7'J' '"'E'-~A'- R ................... C-'E-"O--S'-'U'-"RT--E ............... L~DO GLTEX DEF'TH ~NGI..E D~RECTION LENGTH DEPTH SECTZON TVD C 0 0 R D ! N A T E S DZST~NCE DZRECTZON SEUERZ' FEET D H D H FEET FEEl' FEET FEET FEET FEET D H DG/IOOf~ O, 0 0 0 0 O, 0,00 100. 0 0 0 0 100. 100.00 .... 200* ........ 0 0 .............. 0 ....0 .............. 1~'0~----'2.00';'00 ............... 300. 0 0 0 0 100, 300.00 400, 0 0 0 0 100, 400,00 0,00 -84.00 0,00 0,00 0,00 0 0 0.00: 0.00 16,00 0.00 0,00 0,00 0 0 0,00 0"¥00 ............ ~-'00 .................. ~-;-0-0 0'700' '0~-00 0 ....... 0 ............... 0~00'- 0,00 216.00 0.00 0,00 0,00 0 0 0,00 0,00 316,00 0,00 0,00 0,00 0 0 0,00~ 500, 0 600.. 0 7 00; ......... 0 800. 0 900. 0 0 0 0 100, 500,00 0,00 416,00 0,00 0 0 0 100. 600,00 0,00 516,00 0,00 0 .......... 0 ..... 0 ................. ~'0'0; ....... WO'~T'O-O .................. 070'0 ........ ~'I-'8'¥00 .................... O-'T'O0 0 0 0 100. 800.00 0.00 716,00 0.00 0 0 0 100. 900.00 0,00 816~00 0.00 0,00 0,00 0 0 :~00: 0.00 0,00 0 0 0700 '~rO0 ............... 0 .... ~ .............. 0"~"00: 0,00 0,00 0 0 0o00 0,00 0~00 0 0 0.00 1000. 0 1100. 0 ..... 1200; ..... 0 1300. 1 1400, i 1500, 1 1500, 1 1700. 1 1800, 1 1900. i 0 0 0 0 0 0 45 '-S -' 22 .....O'"'W OS 7 OW OS 3 0 E 0 S 11 15 S 16 15 'S 13 15 S 4 0 S 8 100 ~?:,::::~ O00. O0 ~,~ 0.00 916,00 0.00 0.00 ~i':: ~<i::::~' ~, . i . 1 O0~;:::::;:<l 1 O0 .-00~~ 0 · O0 0 · O0 00. 1499.9,, 1.41 14I'5'~,,~,,,,:,.,'~.~-,,,<~_~,,~:,5~-,~,~S 0,81 W ~ 60 S 8 16 W 0~24 -2 0 W 100~ 1~99.94 ..07 1S15~94~ 7,47 S 1~27 W 7~57 S '- 0 '"W ..... 1'00~ .... 1'6-99T'91- .......................... ='2-~84 ........ 1'-~'I'57-91 .................. 0 W 100. 1799,89 -3,39 1715.89 11+73 S 2~14 W 11+93 S 10 19 W 0.20 0 E 100 1899 87 -3 ~4 1815 87 13 69 S ~07 W 13 85 0,00 0 0 0,00 0,00 0 0 0~00. 0'~5 .......S--22 ....... O-W ........ 2,17 S 16 45 W 0,34 3,88 S 10 11W 0,17 2000. 1 2100. 1 ........ 2200~ ..... 2300. 1 2400. 1 0 S 24 0 E 100, 1999,85 -3,24. 1915,85 15,37 S 1,59 W 15.45 S 5 54 W 0 S 27 0 E 100, 2099,84 -2,67 2015,84 16,94 S 0,84 W 16,96 S 2 49 W 0.05: 15 S 27 0 E 100, 2299,80 -1,26 2215,80 20,67 S 0,98 E 20,69 S 2 43 E 0,04 15 S 28 0 E 100. 2399,77 -0,47 2315,77 22,60 S 1,99 E 22,69 S 5 2 E 0,02 ,...~,00, I 45 S 36 0 E 100. 2499,74 2600, 2 0 S 40 0 E 100. 2599.68 ....... 2700'-~- ........ ? '-S O"-'S--~.;q .... O--E- ......I-O 0'~ ......... 2-699 2800. 4 0 S 82 0 E 100. 2799.44 2900, 6 15 N 70 0 E 100. 2899,04 0,67 2415,74 24,82 S 3.37 E 25,05 S 7 45 E 0.54 2,39 2515.68 27,40 S 5,39 E 27,93 S 11 8 E 0.28 9.89 2715,44 32.17 S 13,'46 E 34.87 S. 22 42 E 2.14: 18,74 2815,04 31.25 S 22,25 E IfS 13, WEL. L NO.* 22 GMS JOB 'NO: AO682G0443 TIME DA'TE F'RUBHOE 'BAY, NORTH SLOPE:,- ..... AL-~'SKA PAGE NO. z" TRUE M E: A S lj R.F.. F.; --D R I F T .... -D R I F' 1 ........ %qOtl. R S E--ME1E'T-I-CAL"--t~ E R lr"I'--CA- k: ....... SUB SEA ............... R--E:--'6'-. --T--A--N--G--U -C:-A--R ........... C --L-O-S~-U- R--E DS-G b-E~G- DEPTH ANGL. E DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE OIRECTION SEVERIT' FEET D M D M FE:ET FEET FEET FEE]' FEET FEET D M DG/iOOF' 3000, 9 15 N 59 0 E 100, 2998,11 31.45 2914~11 25,45 S 34,40 E 42,80 S 53 30 E 3.33 3100, 11 15 N 58 0 E 100, 3096,_~;1 47,53 301o~..51 16,16 S 49,58 E 52,14 S 71 57 E ,.,~ 01 3300, 14 45 N 66 0 E 100, 3291,16 89,79 5207.16 5,95 N 89,68 E 89,87 N 86 12 E 1,92 3400, 16 45 N 70 0 E 100, 3387,40 115,91 3303,40 16,12 N 114,84 E 115,96 N 82 1E 2,27 3500, 19 15 N 70 0 E 100, 3482.49 145.92 3398,49 26,69 N 143,87 E 146,33 N 79 29 E ~ 50 3600. 22 0 N 70 0 E 100, 3576,08 180,12 3492,08 38,73 N 176,97 E 181.16 N 77 39 E ~75 3700~ '2530~N 72 OE ....... I00'~ .....~7"~59 ............ 2t-'9"~'39 .....3583"T59 ............... 5"1-~4-~~2i~-04--E ............... 22i-'~-~2~ ........ N-~8--~'~--E ....... Dr5~- 3800, 28 45 N 73 0 E 100, 3756+58 264,10 ~672.58 65,55 N 258,52 E 266,70 N 75 46 E 3.28 3900, 29 45 N 73 0 E 100, 3843,83 312.10 ~759,83 79,84 N 305.25 E 315.51 N 75 21 E 1,00 4000. 30 0 N 73 0 E 4100, 30 0 N 73 0 E '4200; ...... 29--30-N-73 O-E 4300. 30 30 N 75 0 E 4400. ~.9 3o N 7~ 0 E 4500, 29 30 N 76 0 E 4600. 29 0 N 77 0 E 100,___,.~9 ,...,4 ....... Z, 61,O,., 3846.~_4 94,40 N ~,...,88 E 00 0 14~;~::0. 109,0--N 400, 70 E 03 ~0 I E 4364,20 606, SO 42¢~,,, 2~'7-:'0L~'~'~¢~ 592 + 18 E 365,29 N 75 1 E 0,25 415.26 N 74 47 E 0,00 464-~-86 ..... -N.-.-F-4--~5-E ............ OTS-O--~ 514.86 N 74 32 E 1.41 564,86 N 74 ~4 E 1.00 100, 614,09 N 74 39 E 0,49 100, 4451,45 654.77 4367,45 173,99 N 6~9,69 E 662.93 N 74 47 E 0,70 4800, 29 0 N 78 0 E 100, 4626,16 751,57 4542,16 194,64 N 7~4.82 E 760,16 N 75 10 E 0,25 4900, 28 45 N 79 0 E 100, 4713,73 799,66 46~.9 ..... 73 204,27 N 782,14 E 808.37 N 7~, 22 E 0~54 5000 29 0 N 80 0 E 100 4801 SO 847 81 4717.30 913,07 N .829 61 E 856 54 N ' ' * * ~. + , .~ 36 E 4 5100, 29 0 N 80 0 E 100, 4888,76 896,18 4804,76 221,49 N 877,36 E 904.88 N 75 50 E 0,00 ..... 5200'7 ...... 293'0'"N"-80 O'-'E---~O0~ ..... 4~'76-~-0-1 ......... 9-44'~9'4 .......... 4"8'92'T0'~ .... ~'~T.9~--N~9~5~48--E ..... ~'5~ST6~---N-~6 ....... 5300, SO 45 N 80 0 E 100, 5062+50 995,02 4978,50 238,68 N 974+90 E 1003,70 N 76 15 E 1,25 5400, S0 45 N 80 0 E 100, 5148,44 1046,04 5064,44 247.56 N 1025,26 E 1054,72 N 76 26 E 0,00 5500. SO 0 N 80 0 E 1000 5234,71 1096,49 5150.7i 256,34 N 1075,05 E 1105,19 N 76 35 E 0,75 5600. 30 0 N 79 0 E 100, 5321,31 1146,35 5237,31 265,46 N 1124.22 E 1155~13 N 76 43 E 0~50 .... 57007- .... 30 ...... I-5"'N-79 ........ O-E: .......... 1~00~ ........ 5'40~T8~ ......... t~96~'-'3'6 ..... ~'S~23'~'~&:I95-~O~-ikP---1-1-7-S~--E ..... ~05~28 ...... N-,.76-~,9-~E ...... ~T~5~- 5800. 30 15 N 80 0 E 100, 5494.19 1246.60. 5410,19 284,21 N. 1223,02 E 1255.60 N 76 55 E 0.50 5900, S0 15 N 81 0 E 100, 5580~58 1296,89 5496~58 292.5G N 1272~70 E 1305,89 N 77 3 E 0,50 .............. )])S 13, WEI...L .NO,* 2.2 GMS JOB' NO~* A0682G044S TIME ][JCtTE F'RUOHOE BAY ,' NORTH S',L'OF'E, AI,A'SKA 1~"*"°., ~ ~:.6 ,* ............. S8 O.:.-dUlz~ ............. '"",qq,.. ~. TRUE Pi E A SI.JR IS'.. D""' D R I'F T ............. TJ R'I'F "[ ........... C O!J RSE"""VERTI'-C;"A'I~--- ~ER'TI C'AI~ ..........S UBBE A .......... tq:-"E"'""C-'"'T-~'--N--C~-"U-"E:-i~--F~ ................. C"-'L:""O--$"'--U-'" R--EY .... -:' ..... -D'O O tz-E~i! DEPTH ANGI.,.E DIRECTION I..,ENGTF! DEPTH SECTION TVD C O O R D I N A T E S DISTANCE DIRECTION SEVERI~ FEET D M D M FEET FEET FEET FEEl' FEET FEET D M .OG/100F 6000, S1 0 N 80 0 E 100, 5666,6S 1S47,75 5582,6S S00,9S N 1S22,94 E 1S56,74 N 77 11E 0,91 6100, S0 15 N 80 0 E 100, 5752~68 1S98,58 5668,68 S09,78 N 1S7S,11E 1407,62 N 77 17 E 0,75 6300, 31 SO N 81 0 E 100, 5924~22 1501,20 5840,22 327,19 N 1474,44 E 1510,31 N 77 29 E 0.72 6400. S1 15 N 80 0 E 100, 6009,60 155S,18 5925,60 S~5,78 N 1525,79 E 1562,~0 N 77 S5 E 0,58 6800, 3.1, 0 N 81 30 E 6900, 3.1. .1.5 N 81 SO E 6500, 31 SO N 80 0 E 100, 6094,98 1605,1S 6010,98 ~44,82 N 1577,06 E 1614032 N 77 40 E 6600, S1 0 N 80 0 E 100, 6180,47 1656,89 6096,47 $53,83 N 1628~15 E 1666,15 N 77 44 E '-..~50 ........ 6'700;' 31 15N-"81 O-E ......... 1'00-; ~'2~6'T07 ........1~08~50 ..........6'1-82¥-07 ........ S~2'-T-~"~'-~ .... 1~-'79,";~--~-E~ .... ~-7'i9¥'79 ...... 100, 6351,67 1760,14 6267,67 370,22 N 1730,22 E 1769+39 N 77 55 E 0,36 100, 6437,28 1811,79 6353,28 377,87 N 1781~35 E 1820,98 N 78 1E 0,25 7000, 31 0 N 81 0 E 7100, SO 45 N 81 0 E 7200;'-' SO 15'-N~80 30'E 7300, SO 0 N 80 0 E 7400, 29 15 N 79 SO E .522 , 100~ ......... .~ ,88~63,4S 6438,88 .-~85,7~ N 18~9,4-~-E 1872 59 N 78 7 E 0 100~ii:~ 608,71~~ 39S,76 N 188S~12 E 1923~85 N 78 11 E 0,25 ~: -~-, ~,~ ~ ~ ~ ~ ~ ~f .. ~.~ .................. ~ ......~ ........... ~ . 10 6781,S7 201~$~6~6687,S7 e410,41~ I 68 E 2024,71 N 7500, 29 0 N 79 SO E 100 .. , 6955,65 211S,~1 687%~5%~"~,2~)O~f~N o079,18 E 2122,79 N 78 22 E 0,25 7600. , 28 45 N 79 S0 E 100, 7043,9~.._ ..~161,46 6959~.°~... 436,88 N ..~126~66 E 2171~07 N. ~R... .,.~. E 0~25 ..... 7700, 27 45 N-80 O-'E I00¥ ....... 7800. 27 15 N 80 0 E 100. 7220~01 2254,75 7136,01 45S,32 N 2218~71 E 2264,54 N 78 27 E 0~50 7900, 26 45 N 80 0 E 100, 7~09,11 2~00~05 7225,11 461,20 N 226~42 E 2509~9S N 78 29 E 0,50 8000, . 26 0 N 80 0 E 100, 7398,70 2344,38 7314,70 468,92 N 2307,17 E 2354,34 N 78 S1E "~75 8100, ..~5 15 N 80 0 E 100, 7488,86 2S87,~ 7404,86 476,4S N 2S49,76. E ~.~7,57~.. . N 78 .,~.~ E 0,75 8~. 0 O, ~. ~ ........ 0 'N--79'-30--E----I~O-T----7o~9-~-40- ~.4~9'~-88 .......~'4'95~-40 ....... 48~ ,--96~-N- ~.S-9"~'~'4--~ ..... z440 ~'-Oz' .......... N'--~8 "-~'4 ..... E .......... O~SS 8S00, 24 15 N 79 SO E 100, 7670,S0 2471,44 7~86 S0 491 ~ N i E 81 68 N 78 75 E 0,75 8400, 2S 1=.., N 80 SO E 100, 7761 ,8S .~511,62 7677o8S 498,5..7 N ..~47~, 17 E 2521, 9.4 N 78 ~6 E 1 , 08: 8500, ........... oo 15 N 81 30 E 100, 7854,05 2550,~ 7770,05 504,62 N ~510,36 E ~='60,,58 N 78 38 E 1,07 587 28 7862,93 509,94 N 2547 OS E 2597 u8 N 78 41 E 1,02 8600, 21 15 N 82 0 E 100, 7946,93 2 ,.700, .,.0-'0-N--8~-30--5 I~0, 8040,-5'~ 8800 17 45 N 84 0 E 100 81~ . , ~.14 2654 84 8051 14 518 49 N 2614 06 E 2664,98 N. 78 47 E ~ ~0 8900. 16 0 N 85 0 E 100, 82S0.8~ 268~.86 8146.8~ 521.27 N 2642,95 E 269J,87 N 78 51E 1,77 JOB'NO~ A068260443 COMFL. iA~ION TIME D~TE rAG~ NO, 4" TRLIE · M E~I..-!SL.~E~f~.'F~T----~fR . . ,..~ . · "~'f~%~ql~M E-E~T'-I"CCTL5- ..... SU-B'~'A ....... DEF'TFI ANGL. E DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT' FEET 0 M D M FEET FEET FEET FEET FEET FEET D M DG/100F' 9000, 15 0 N 86 0 E 100, 8327,19 2710.57 8243,19 523,37 N 2669,59 E 2720,41 N 78 54 E 1,04 9100. 15 0 N 87 30 E 100, 8423.78 2736,42 8339.78 524.84 N 2695.43 E 2746,06 N 78 59 E 0~39 9~,~.00. ........... ~'~-~'5--N-87 ..... ~--E?~--1_~0'7---8~:~0'~"S .... ~7'~?.."¥'04---84~4~ .... --~2'6's~O~--N----2~.~OS--~--~-F-'t-T4'67---N--~-Sx---S--~--~?28 ..... 9300, 14 0 N 88 0 E 100. 8617.S0 2786,82 8533.30 527.15 N 2745,88 E 2796.02 N 79 8 E 0~79 9400, 13 45 N 88 30 E 100. 8714,38 2810,72 8630.38 527,88 N 2769,85 E 2819.70 N 79 13 E 0,28 9500. 13 0 N 89 0 E 100. 8811.67 2833,77 8727,67 528.39 N 2792,98 E 2842,52 N 79 17 E 76 9600, 12 30 N 89 0 E 100. 8909,20 2855,75 8825,20 528,77 N 2815,04 E 2864,27 N 79 22 E '450 '9700~ .... 12'15-'N"89 O-E .............. 1-0'0~ ...... 9006?88 ........ 287'7~-09 ...... 8922~'88 .......... 5'29~d.5--N'~,._qIBS-8-~-4-7--E-~2885¥'40 .... '-N--~9-'-25--~ ......... -0.?25-- 9800. 12 0 N 88 30 E 100. 9104,65 2898.01 9020,65 529,60 N 2857,47 E 2906.13 N 79 30 E 0.27 9850. 12 0 N 88 30 E 50. 9153.55 2908,37 9069.55 529.88 N 2867.86 E 2916,40 N 79 32 E 0,00 F'RO:.IECTED TO 9902 MD -. ~Z , THE FOLLOWING STATION IS F'ROJE FOR' INTERF'~ ; 9924. 1° 0 N 88 30 E oo 9,,.~.o.94 ,.9=.,.~71 914"~~0L~~B~ ~.88~.~4 E ~ ~ ~ 82 29 28 82 9975. 12 0 N 88 30 E .:,1, 9~.7~, .. 34, 9191, 2927 'tO'8 ...... N-'79'"'-3'4-'E' ........... 0-'~'-'0 (~ 2931.60 N 79 35 E 530.56 N 2893,84 E 2942.07 N 79 37 E 0~00 0.00 FINAL CL. OSURE - DIRECTION,' N 79 DEGS 36 MINS 39 SECS E ........................................... Ir ,]~S~T-AN C.. E-~ .... -2 ~4?~-O"?--F'EE-T-' ARCO ALASKA, INC,. .OS .1. S: WE[._[_ NO ~ 22 ....... G'PIS ................................................................................... ::]OB-NO ~* ....... iA'O582GO'4'zl,?. , I::'RU][)FIOE [{AY, NORTH SLOF'E, AL. ASKA GMS, 0-9'850 MD, SURVEYOR~ CORAM/JAHN ..... ..,6.~., 6 CAMERA NO,* :I. R7.°, S287 GYRO NO 5-90 ]')EG., A/U N.O** .l 562, 1562 FORESIGHT~ N 10 W ELATE: RUN~ 16-~JUN-82 JOB'NO| A0682G0443 COi"t~-'Li i'A "i i TIME DA'TE MARKER TRUE SUBSEA NAME DEPTH DEPTH DIFF DEPTH C 0 0 R D I N A T E S DISTANCE DIRECTION THICKNESS FEET FEET FEET FEET FEET FEET D TOP OF SADLEROCHIT O/W CONTACT TD 9560.00 8870.1~ 68~,8 8786+19 528.62 N 2806~22 E 2855~57 N 79 20 E ~7~4.00 ~098~78 695.2 9014.78 52~.58 N 2856.21 E 2904.8~ N 7~ 30 E 9975.00 9275.82 6~.2 ~1~1~82 530.56 N 28~3.84 E 2~42.07 N 79 37 E Eastman/ WhipstOck l A PETROI..ANE COMPANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY ARCO ALASKA, INC. COMPANY DS 13, Well Number: 22 WELL NAME Prudhoe Bay, North Slope, Alaska LOCATION JOB NUMBER TYPE OF SURVEY DATE Directional Single Shot 25-May-82 RECEIVED SURVEY BY J U L - 8 2982 Alaska Oil & Gas Cons. ColnrnJssion Anchorage OFFICE Controlled Drilling Consultants (Dale Hendrix) ARCO 'ALASKA,' INC,' .................................................................................................... ' .......-' DS 1~, WEI._L. NO: 22 DSS (CDC) PR[U)HOE BAY~ NORTH SL. OF'E~ ALASKA ........ D~, ....... 0~4~''''HDF ..... [~RT~I2~R"~-~IAE~N~R~X 25~HAY:82 R~GI ROWAN 2& [IECI..INATION; ~0 1/2 'DE:G° EAST DIR£CTIONAL COHF'ANY; CONTROLLE])DRILLING CONSULTANTS SURVEY F'ROVI[IE]] BY' CDC I~E I:;: 1' I [;At.. RECORD OF"SURVEY RABIUS OF CURVATURE METHOD ARCO AL. ASKA~ IN.C,~ COt'iF'IJTATION F'AGE [~S 13, WEL. L · F'RU[IHOE BAY, NORTH SLOPE, ALASKA 15130104 18-JUN-82 .................. TRUE " ' rflEASURE[m i)RIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U E E [mOGLE[~ DEPTH ANGL. E [mIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE [IIRECTION SEVERII' FEET D M [~ M FEET ' FEET' ......... FEET ................... FEET ......................................... FEE'T ............................................... FEET ....................... [~ .... H .............. [~G/IOOF' O· 2500. 2575. 2664· 2755. · 0 0 0 0 0 0 O' 0 2 0S19 OE 3 0S47 OE 245S47 OE O. 0·00 0000 -84.00 0,00 0·00 0.00 0 0 0·00 2500,2500.00 ................... 0;'00 .... 2416.00 .............. 0';'00 ................... 0,00 .................. 0";00 ...... O0 ................. 0,00 73. 2572,99 0.28 2488,99 1,20 S 0,41 E 1,27 S 19 0 E 2,74 91. 2663·90 2,05 2579.?0 4.50 S 2.55 E 5,17 S 29 35 E 1·70 91. 2754;'78 ............. 5';03 ......2670';'78' 7;~'1"-S ............... 5;'89-"E ................ 9;63 S'"37"45"E ...... 0~27 2849. 4 45 S 77 0 E 94. 2848.58 10.06 2764,58 10.47 S 11.26 E 15.37 S 47 5 E 2943, 7 0 N 74 0 E "' 94.' 2942~'08 .............. 1'9"~'55 .....2858;-08 ................ 1'0";'22'-'~ ............ 20.77--'E ............. 23';]'5 ......S'"~3" 49"E ........... 3'89 3037, 9 30 N 67 0 E 94. 3035.10 32.66 2951.10 5.72 S 33.48 E 33·96 S 80 19 E 2,86 3129. 11 30 N 66 0 E 92. 3125.55 48.67 3041,55 0.97 N 48.85 E 48.86 N 88 52 E 2.18 3.-,=3. 13 30 N 66 0 E 94.--3217;32 ........... ~;'8';'04 ...... 31'33.32'-' ............. 9;"24--N ............. 67,44""E ................ 68.07 N"82 "1~ ............ E ~..13~'- I ~;i ~:: ".~ .~'~ ~:~' ~'' '~ ~ ' o:' ~/'":' o ~... ..... ~'~ . "' ~ ' ' """' ' :~ ~ ~'~"~:' ;' ':?~ ~ .... E 114.59 N 77"40"'E 3408, 16 30 N 74 0 E 9~,~.~..:~396,~0:II~1.3:1~.4~3~13:,..~ 2'25 3532. 19 45 N 75 0 E 124'~;~3514,04 15~,~0~)~3430,04 ~ 34,6~j~_.~..~.. ~~'~:11 E 153.1o ~ N 76 =~.~ E 2.63 E 211.09 N 76 E 3.09 3812. 28 45 N 77 0 E 126. '~'~3'~6~J~:'~;~26~3~3~'~P-~'6~4~i ~60~.14 E 267"54 ........ N 76'30"-E ......... 3;39 4304, 30 0 N 78 0 E 492, 4198,00 505,25 4114,00 114,72 N 495.75 E 508,85 N 7& 58 E 0.27 4829, 29 30 N 78 0 E 525,' 4653;80 ........... 76'4"44 ..... 4569,80"; .... 168";'89'"N ............. 750,57-'"E ......... 769~33 ..... N"77' 19'E ........... 0;'10 5092, 29 30 N 80 0 E 263, 4882,71 893,49 4798.71 193,60 N 877,&9 E 898,79 N 77 34 E 0.37 5595, 30 30 N 82 0 E 503. 5318,31 1144.&8 5234.31 ~.3~,94 N 1126.07 E 1149,91 N 78 6170. 31 0 N '80' 0 "'E .....575" .......5812'~47 ...... 1'4'38';'31' ....... 5728;'47 ........ 278'793-N ..... 1'416"43""E ............ 1443';"64 .......N' .~8 E 1632,&2 6537, 31 0 N 80 0 E 367, 6127,05 1626,92 6043,05 311.75 N 1602 ~ N 79 0 E 6847, 31 30 N 79 ....0 E .... 310, .... 6392"07 ....... ~787';29 "6308~"07 ........ 34I'-;06--'N .......1760,71 ..... E ....... 1793;43 ...... N'79 ..... 2'-E ........... 0,23 7039, 31 30 N 80 0 E 192, 6555,78 1887.32 6471.78 -359,34 N 1859.35 E 1893,75 N 79 4 E 0,27 7329. 30 0 N 78 0 E 290. 6805,00 2035,07 6721.00 387,63 N 2004,89 E 2042.02 N 79 3 E 0.63 , .... 419.~3 N .~)~4,?& E ~.1'95';'41 .......... N"78"5~"-E ............ 0,48 7643 28 30 N 78 O'E 314'; .... 7078~?& .... 2187;-72 ..... &??4'~?& ........... ~ .............. ~'"= ............. · 7~6.,.75 449,15 N ,32 E 2337,87 N 78 55 E 0,4? 7949 27 0 N 78 0 E 306, 7349,75 2329,46 -o = 2294 "8319, ..... 24"'30 N 79 O'E ........ 370; .......7682T?? ...... 248~;-51 ..... 7598~99 ......... 48~;~?--N .... 2451'-;82-E~2498;-59 ..... 8625. 21 0 N 79 30 E 306. 7965,14 2607,46 7881,14 503,26 N 2568.06 E 2616.91 N 78 55 E 8930, 16 15 N 83 0 E 305, 8254,08 2704,73 8170.08 518,07 N 2664.2? E 2714.20 N 79 0 E 1.60 .... 9377; ........ 1'4'0'N 84 ..... O'E ........... 447', .......... 8~85;57 ....... 2821'¥35 ....... 8~0"1";5'7 ....... 531"727--N~2780;'IT-'F2830;~8 ..... N'"'"'79-1'-I-E ..... 0;51 ,':IR£;O ALASKA, INC, 1,3', WELL~ NO; 22 [JSS F'RIJ[IHOE BAY, NORTH SLOPE, ALASKA '(-CD'C) COMPUTATION T I'ME "[rAT E 15; 30; 04 1 B-JUN-B2 PAGE NO~ ,2 ............................ FRU£ " HEASURE[I DRIFT DRIFT COURSE VERTICAL VERTICAl. SUBSEA R E C T A N O LJ l.. A R C L 0 S L! R E DOGI_E~!~ [mEF'TH ANGLE DIREC'I'ION LENGTH DEPTH SECTION TVD C 0 O R D I N A l' E S DISTANCE DIRECTION SEVERIT FEET' ' D H ..... [m 'H ...... FEET ............... FEET ............. FEET ................ FEE1 ~FEE1 FEET ......................... D ..... M ......DG/I'OOF 9945° 12 0 N 89 0 E 568. 9238°98 2948,93 9154o98 539,07 N 2907.66 E 2957o21 N 79 30 E 0.40 FINAL CLOSURE - DIRECTION; DISTANCE; N 79 DEOS 29 HINS 48 SECS E '2957;21"FEET .............................................................................................................................................................................. A t::'i_il i I( )l Ah/ti C:C~4/:~ANY Al:;~f.;O ALASKA, INC, !';e,c; 13, WELl.. NO| 22 DSS FRLIDHOE. 8AY~ NOf~IH fll..ofiE~ IL. IiI [IE;F'I'H 533.00 2730.00 4842.00 94~2.00 BOTTOM 'HOLE VALUES USE[~ FOR DEPTH ARE [~ES[;RIF'I'ION F'EN[jLJI..LIH ASSHE':E~I.y ~ ~ ~ ' DR I L L. I NG DA Y S 4 t';L::/'fK)1.4N~:~ COMF~NY ~I..UES ~BEl:l FOR lIEF'TH ~RE HD 1) A Y 1 2 4 5 7 10 :1.1 12 173 14 15 lIEF'TH · 533.00 2526.00 2993.00 4842.00 5983.00 6760.00 7208.00 8405.00 9~50.00 9462.00 94~2.00 9462.00 94~2.00 9945.00 t ' WEIGHT ON BIT WEIGHT !S GIUEN PER 1000 F'OUNDS UAL. LIES' USE[! ' FOR'"[IEPTH"' ARE' MrJ DEPTH WE' I GHT 533,00 2730.00 4842°00 94&2~00 ... D E F' 1' H 533,00 27M0.00 4842,00 45'.00 10.00 70,00 85.00 REVOLUTIONS F'ER-MINUTE UAL. LIES USED FOR BEF'TH ARE l&O,O0 50°00 '?0o00 100.00 A / :'i: tF~( .)! .,,iN/:. C( '. ,,..' I , ~ I.IF, IL.r: ~ L.n~"11% I ' : ' ,, · .I ,,, ,,, /~;: ,~ i ! ~r~ ,, ' ! '! 'I " ,,.,,,¢1 ' ' ' .' ,:' " :i : ' ! '--~ ; ' ; " .... ~ I '' : ' ' ' ''' I,' i ' : : , , , : , · , ~ I ~ , , i . "" , ~ -ARCO-.ALASEA, INC. PRUDHOE BAY, NORTH SLOF'E, AL. ASEA GMS, 0-9850 MD, SURVEYOR; CORAM/JAHN CAMERA NO; 1572, 3287 GYRO NO; 562, 632 5-90 DEG, A/U NO; 1562, 1562 FORESIGHT; N 10 W DATE RUN; 16-JUN-82 VERTICAL SECTION CA[..CULATEW'~6LANE~~~~-~-- · A PETFIOLANE COMPANY RECORD OF SURVEY RADIUS OF CURVATURE METHOD ARCO AL. ASKA, INC, DS '13, WEI. L NO; 22 .GMS 'PRUDHOE- BAY-, .......... NO R TH-'"'S[OPE"F'-"A I:'ASKA JOB'NO~ AO682G0443 TIME DATE I'RUE ~E~ASO~E~j'-[i~TFT~D~TFT----lY. OUR'~.~."C~ERT~CAK-IJERTIC'~~BS~A--~-tZ--C-T-~--N--G-~J ~ A R C-l: 0 ~ U ~. £ ~OGL.£O DEPTH ANGL. E DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D M D M' FEET FEET FEET FEET FEET FEET D M DG/100FT O. 0 0 0 0 O. 0.00 0.00 -84.00 0.00 0.00 0.00 0 0 0.00 100. 0 0 0 0 100. 100.00 0.00 16.00 0.00 0.00 0.00 0 0 0.00 ......... 2'00~ ........ D ....O ....... 0 ........ 0' IO"0-;-: ....20'O¥00''----OTO0-~T~;-O0~-O~00 0T00 .................0'~O0 ............... 0 ...... 0 ............... 0'~'00 .... 300. 0 0 0 0 100, 300.00 0,00 216,00 0,00 0.00 0,00 0 0 0.00 400. 0 0 0 0 100o 400,00 0.00 316,00 0,00 0.00 0,00 0 0 0,00 ~/~'-.500, · 0 0 0 0 100o 500.00 0,00 416,00 0,00 0,00 0.00 0 0 0,00 600, 0 0 0 0 100. 600.00 0.00 516o00 0,00 0,00 0,00 0 0 0.00 800. 0 0 0 0 100. 800,00 0.00 716.00 0.00 0.00 0.00 0 0 0.00 900, 0 0 0 0 100. 900.00 0,00 816,00 0.00 0,00 0,00 0 0 0,00 1000. 0 0 0 0 1100. 0 0 0 0 ..... I2001 .......... 1300. 1 0 S 7 0 W 1400, I 0 S 3 0 E 1500, I 0 S 11 0 W 1600, i 15 S 16 0 W 1800, 1 15 S 4 0 W 100, 1799.89 1900. i 0 S 8 0 E 100, 1899.87 0,00 0 0 0.00 0,00 0 0 0.00 0~5 ...... ~'-'22 ....... 0"W ......... 0~-95 ..... 2,17 S 16 45 W 0,34 3,88 S 10 11W 0,17 100, 5,62 S 8 16 W 0,24 100. 1599.94 -2,07 1515,94 7,47 S 1.27 W 7,57 S 9 38 W 0,27 -3,39 1715,89 11,73 S 2.14 W 11,93 S 10 19 W 0,20 -3~54 1815,87 13,69 S 2.07 W 13,85 S 8 ~5 W 0,34 ~000, I 0 S 24 0 E: 100, 1999,85 -3,24. 1915,85 15,37 S 1.59 W 15,45 S 5 54 W 0,28 2100, 1 0 S 27 0 E 100, 2099.84 -2.67 2015,84 16.94 S 0.84 W 16,96 S 2 49 W 0.05 ~'-"'2200~ ................. I ...... I'5""-$"~25 ........ 0-'~ ........ I'O0'~ ...... 2~?'~-8~~'- ....... ~2~0~2I~5~82 ...... --'t'8~-'~ .......... O'~-03-E ......... ~8~'~'! ...... S ........ 0 ....... 5'--E ......... 0~'-~5'- 2300, 1 15 S 27 O E 100, 2299.80 -1.26 2215,80 20,67 S 0.98 E: 20,69 S 2 43 E 0,04 2400, 1 15 S 28 0 E 100, 2399.77 -0,47 2315,77 22,60 S 1.99 E 22.69 S 5 2 E 0,02 2500. 1 45 S 56 0 E 100, 2499,74 0.67 2415,74 24,82 S 3.37 E 25,05 S 7 45 E 0,54 2600. 2 0 S 40 0 E 100, 2599,68 2.39 2515,68 27.40 S 5.39 E 27,93 S 11 8 E 0,28 ..... 2?00; ....... 2-~0-~"-54 ..... ~}-'~ ..... ~00"~ ........ ~679'~'6t ......... ~T~'5---:26~5-~-'6~ ..... 30'-~-(:h~--S ....... 8.'RS--E ....... 3-1-~.8~-S--t~"-~1-----E ...... 0-~4 ..... 2800, 4 0 S 82 0 E 100, 2799,44 9.89 2715,44 32,17 S 13.'46 E 34,87 S 22 42 E 2,14 2900. 6 15 N 70 0 E 100. 2899.04 18.74 2815,04 31.25 S 22.25 E 38,36 S 35 27 E 3.30 AF~£.'.O ALASKA, IN[.'., COHPUTAI'ION PAG;.: NO,. 2 !DS.13, WELl. NO; 22 GMS JOB'NO; AO682G0443 TIME DATE · TRUE DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D M D M FEET FEEl' FEET FEET ' FEET FEET D M DG/iOOFT 3000, 9 15 N 59 0 E 100, 2998,11 31,45 2914.11 25,45 S 34.40 E 42,80 S 53 30 E 3.33 3100, 11 15 N 58 0 E 100, 3096,51 47,53 3012,51 16,16 S 49,58 E 52,14 S 71 57 E 2.01 3300, 14 45 N 66 0 E 100, 3291,16 89,79 3207,16 5,95 N 89.68 E 89,87 N 86 12 E 1,92 3400, 16 45 N 70 0 E ' 100. 3387,40 115,91 3303,40 16,12 N 114,84 E 115,96 N 82 1 E 2,27 ~-3500, 19 15 N 70 0 E 100, 3482,49 145,92 3398,49 26,69 N 143,87 E 146,33 N 79 29 E 2.50 ~600,. 22 0 N 70 0 E 100. 3576,08 180,12 3492,08 38,73 N 176.97 E 181,16 N 77 39 E 2,75 ~-3700~ ...... 25-'~0--N-72 ........ 0--~--"---I00-~--~6'~5~~- ....... 3800, 28 45 N 7~ 0 E 100, ~756,58 264,10 ~672,58 65+55 N 258.52 E 266,70 N 75 46 E 5.28 ~00, 2~ 45 N 7~ 0 E 100, ~84~.85 ~12,10 575~,8~ 7~,84 N ~05.25 E 515.51 N 75 21E 1,00 4000, 30 0 N 73 0 E 4100, 30 0 N 73 0 E 4300. 30 30 N 75 0 E 4400. 29 30 N 75 0 E 4500, 29 30 N 76 0 E 4600, 29 0 N 77 0 E 100~~.~93Q,54~61,03 3846,54 94,40 N 352,88 E 365,29' N 75 1 E 0,25 10 {41~0,57 5~j,~6~841~6,~7.~137,31 ~ ~21E 514,86 N 74 32 E 1,41 10~ ~5~ 51 E 564,86 N 74 34 E 1,00 100, 4364,20 606,30 100, 4451,45 654,77 4367,45 173,?? N 6~,6~. E 662,93 N 74 47 E 0,70 4800, 29 0 N 78 0 E 100, 4626,16 751,57 4542,16 194,64 N 7~4,82 E 760,16 N 75 10 E 0,25 4900, 28 45 N 79 0 E 100, 4713,73 7~,66 4629,73 204,27 N 782,14 E 808~37 N 75 22 E 0,54 5000, 29 0 N 80 0 E 100, 4801,30 847,81 4717,30 213,07 N 829.61E 856,54 N 75 36 E 0~54 5100, 29 0 N 80 0 E 100, 4888,76 896,18 4804,76 ~1,49 N 877,36 E 904,88 N 75 50 E 0,00 5300, 30 45 N 80 0 E 100, 5062,50 995.02 4978,50 238,68 N 974.90 E 1003,70 N 76 15 E 1.25 5400. 30 45 N 80 0 E 100, 5148,44 1046,04 5064,44 247,56 N 1025.26 E 1054,72 N 76 26 E 0,00 5500. 30 0 N 80 0 E 100. 5234.71 1096,49 5150.71 256,34 N 1075,05 E 1105,19 N 76'. 35 E 0,75 5600, 30 0 N 79 0 E 100, 5321.31 1146.35 5237,31 265.46 N 1124,22 E 1155,13 N 76 43 E 0...~0 5800, 30 15. N 80 0 E 100, 5494.19 1246.60 5410.19 284.21 N- 1223.02 E 1255,60 N 76 55 E 0,50 5900. 30 15 N 81 0 E 100. 5580.58 1296.89 5496.58 ~9~.53 N 1~7~.70 E 1305,89 N 77 3 E 0,50 ARCO AI..ASKA, INC, DS '13, WELL NO; 22 .GMS F'RU'DH OE-~B~AY'~'I-~'NORTH--S[.-OF''E~-''-~I~A~SK'A~ JOB'NO; AO682G0443 TIME DATE TRUE M'[~"~0E'~EF~.i~R~[FT--~i~k-~I~~COI]'RSE'--~ERTIC~A-L~E~'~~UBSE~-~-E-, .... - '- -L:"~v"~*A--R -'C--L--'O-B-U--E--E- ..... DOGLEG" DEPTH ANGLE DIRECTION LENGTH DEF'TH SECTION TV[I C 0 0 R [I I N A T E S DISTANCE DIRECTION SEVERITY FEET D H D H FEET FEET FEET FEET FEET FEET D H DG/IOOFT 6000. 31 0 N 80 0 E 100, 5666,63 1347,75 5582,63 300,73 N 1322,94 E 1356,74 N 77 11E 0,91 6100, 30 15 N 80 0 E: 100, 5752,68 1398,58 5668,68 309,78 N 1373,11E 1407,62 N 77 17 E 0,75 6300, 31 30 N 81 0 E 100, 5?24.22 1501,20 5840.22 327.19 N 1474,44 E 1510,31 N 77 2? E 0,72 6400, 31 15 N 80 0 E 100, 6007,60 1553,18 5725.60 335,78 N 1525.77 E 1562,30 N 77 35 E 0,58 /"%500, 31 30 N 80 0 E 100. 6094,98 1605,13 6010,78 344,82 N 1577,06 E 1614,32 N 77 40 E 0,25 o600, 31 0 N 80 0 E 100, 6180,47 1656,'89 6096,47 353,83 N 1628,15 E 1666,15 N 77 44 E 0.50 6800. 31 0 N 81 30 E 100, 6351,67 1760,14 6267,67 370,22 N 1730,22 E 1767,37 N 77 55.E 0,36 6?00. 31 15 N 81 30 E 100, 6437,28 1811,77 6353,28 377,87 N 1781.35 E 1820,78 N 78 I E 0,25 7000, 31 0 N 81 0 E 100.~.~522.88~63,~3.~ ~ _~___ ._. 6438,88 385,73 N 1832.44 E 1872,57 N 78 7 E 0,36 81 0 E 100~~08',71~~~~ 3~3,7~N :1883,12 E 1723,85 N 78 11E 0,25 7100, ZO 45 N '---7200¥---3'~5'"'-N-B0--3;O'-E: 10~67~, 8~~~~> ~~ ~ 4~ 22 E 1974:-O5--N'--YS-'IS'"-'E ........ Ov',.C-r6 7300, 30 0 N 80 0 E . 10~~781,37..~:.~._. _ =.~_~=____~_______201[,~6~6~7,37 .,_410~1~ 1~&8 E 2024,71 N 78 18 E 0,35 7400, 29 15 N 79 30 E l O0~O&~~~~~~~~ ~32 E 2074,13 N 78 20 E 0,79 7500, 29 0 N 79 30 E 100, 6955,&5 2113,31 h871A~ROL~8~~ 2079.18 E 21~,.~,79 N 78 ~ E 0.25 7600, 28 45 N 79 30 E 100, 7043,22 2161,46 6959,22 436,88 N 2126.66 E 2171,07 N 78 23 E 0,25 -'--7700'~; ............ 2~AS-'N'"'""80 ........ O--'~-'--~O0: ....... 71'-3I"-;3~--2208w&8'-~'~~-44-~~ ....... 2I"7'3:~4-~2~'8~ ..... N-78-'~5~----E ....... t703 7800, 27'15 N 80 0 E 100, 7220,01 2254,75 7!3&,01 453,32 N 2218,71E 2264,54 N 78 27 E 0.50 7?00, 2& 45 N 80 0 E 100, 7307,11 2300,05 7225,11 4&1,20 N 2263,42 E 2~07,73 N 78 27 E 0,50 dO00, . 26 0 N 80 0 E 100, 7398.70 2344.38 7314,70 468.92 N 2307,17 E 2354,34 N 78 31 E: 0,75 8100, 25 15 N 80 0 E 100. 7488,86 2387.53 7404,86 476,43 N 2349.76 E 2397,57 N 78 32 E 0,75 8200¥ ....... 25 8300, 24 15 N 79 30 E 100. 7670,30 2471,44 7586,30 471,58 N 2432.51E 2481,68 N 78 35 E 0,75 8400. 23 15 N 80 30 E 100, 7761.83 2511.62 7677,83 498,57 N 2472.17 E 2521,94 N 78 36 E 1,08 8500, 22 15 N 81 30 E 100. 7854.05 2550.25 7770,05 504,62 N 2510.36 E 2560,58 N 78 38 E 1,07 8600, 21 15 N 82 0 E 100, 7946,93 2587.28 7862,93 509,94 N 2547.03 E 2597,58 N 78 41E 1,02 870~ ..... ~0-~O-N-~82'~'0~E ........... IO0~ ...... 80'4~"5'2 ...... ~6~T4-9-----7956TrCr2'~~4',--6'9--N~.58~9-4--~---~63~---~'-r-~4-~-~8-44-E--~ .... ~-~6 8800, 17 45 N 84 0 E 100, 8135.14 2654,84 8051,14 518,49 N 2614,06 E 2664,98 N 78 47 E 2,30 8900. 16 0 N 85 0 E: 100, 8230.83 2683.86 8146.83 521.27 N 2642.95 E 2693,87 N 78 51E 1,77 ARCO AI..ASKA, INC. DS .1~, HELL NOI 22 .GMS F:'RLIliF[OE-B'A' ~ ,T~-~~O'~TA-SKA JOB'NO: AO682G0443 COHF'U'FA l' I ON T I HE DATE i"~ 26 ~ 38 :;~ 02~UL-82 PAGE i~0. ~, 4 · TRUE M~~ED"~'D'Ri:'F"T ................. ~-iRIFi ........COURSE ....... · AL SUBSEA R E C""T A N G-U-L~R C L O $ U R E DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D H D H FEET FEET FEET FEET FEET FEET D M DG/100FT 9000. 15 0 N 86 0 E 100. 8327.19 2710,57 8243.19 523.37 N 2669.59 E 2720.41 N 78 54 E 1,04 9100. 15 0 N 87'30 E 100. 8423,78 2736,42 83~9,78 524,84 N 2695°43 E 2746.06 N 78 59 E 0,39 9300. 14 0 N 88 0 E 100o 8617.30 2786°82 85~3.30 527,15 N 2745,88 E 2796,02 N 79 8 E 0.79 9400, 13 45 N 88 30 E 100, 8714,38 2810.72 8630,38 527,88 N 2769,85 E 2819.70 N 79 13 E 0,28 9500, 13 0 N 89 0 E 100, 8811.67 2833,77 8727.67 528,~9 N 2792,98 E 2842,52 N 79 17 E 0,76 /"x~600, 12 30 N 89 0 E 100, 8909,20 2855,75 8825,20 528,77 N 2815.04 E 2864,27 N 79 22 E 0,50 9800, 12 0 N 88 30 E 100, 9104,65 2898,01 ~020o65 529,60 N 2857,47 E 2906.13 N 79 30 E 0,27 ~850, 12 0 N 88 30 E 50, ~153,55 2~08,37 ~0&~o55 52~o88 N 2867,86 E 2~1&,40 N 7~ 32 E 0o00 PROJECTED TO 9902 MD ,::-: ; .:' . ~ , ,. o ,.whfpstock ?~24, 12 0 N 88 ZO E 22, 7225,74 2~23,71 A~RO~'~~ 2883,24 E 2731,60 N 7~ 35 E 0,00 7975, 12 0 N 88 30 E 51, ~275,82 2~34,28 ~1~1,82 530,5~ N 2893.84 E 2742,07 N 7~ 37 E 0,00 FINAL CLOSURE - DIRECTION; N 7~ DEGS 36 MINS 37 SECS E ARCO At. ASEA, INC+ PRUDHOE BAY, NORTtt SLOPE, ALASKA GMS, 0-9850 MD, SURVEYOR; CORAM/JAHN JOB-~OF-iqO-6B260~4-4~ CAMERA NO; 1572, ~287 GYRO NO; 562, 632 5-90 DEG. A/U NO; 1562, 1562 FORESIGHTt N. 10 W [;ATE RUN; 16-JUN-82 Eastman ~ A pETROLANE COMPANY ARCO ALASKA, INC, DS .13;, W~.L..L NO; 22 .GMS P R Iir[iF[OE--8'~T~ORTFI-%S[~~A1,.~h~A JOB'NO; ~0682G0443 TIME DATE · MARKER- CODE NAME TRUE SUBSEA _ MEA'SUR£D VEk~I~TVD VE~TiCAEL~R E C T A N G U L ~ ' C L--D S"U R E VERTICA~ DEF'TH DEF'TH DIFF DEF'TH C 0 0 R D I N A,T E S DISTANCE [mlRECTION THICKNESS FEET FEET FEET FEET FEET FEET D M TOP OF SADLEROCHIT O/W CONTACT -p,BT~D TD 9560.00 8870.19 689.8 8786.17 528.'62 N 2806.22 E 2855.57 N 79 20 E 9794.00 9098.78 695.2 9014.78 529.58 N 2856.21E 2904.89 N 79 30 E ??75.00 ?275.82 677.2 7171,82 530.56 N 2893,84 E 2?42°07 N 7? 37 E tman ..... -' APE TROLANE COMPANY Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · -' Ope. ratdr, Well Name and Number Reports and Materials to be received by: ~--/~- Date Required Date Received RemarkS ·Ccmp !erie n Rape rt Yes Well History Yes _Samples :.:/~ -P ,, · ~, .... . , .... ~ ..... ~ ,, , , ~ ,, ,, , , Core Chips .............. ~~~, ----- d fi~:' ' ~,, ....... , Core ~scription ~, . ,, ...... ,, . ............ . , [ ...... , Registered S~, ~la~ 7~.~ ~_/~_~ ..... ~..~, t- ,, , ~ , ....... , ........... Inclination Su~ey ~ , s, _ ,,, ..' '~" ~ ,_ , ,, , Drill St~ Test Returns ~X ~ ,,, ,, _ ,, ..... Pr~u~on T~g Re~s .._ ~ ~~ ..... ~ A ...... ~~, ~s ~-, ox- ~ la,,,,,,!.~.. ......... , , , STRATIGRAPHIC HIGH RE'SOLUTION DIP METER LOCATED IN THE APPENDIX Anchorage. Alaska 99510 ' Telephone 907" w)5637 July 8, .1982 Reference: ARCO DIRECTIONAL DATA 6/16/82 Gyroscopic Job No. A0862G0443 D.S.15-5 5/20/82 Gyroscopic Job No. A0582G0435 se sign and return the attached copy as receipt of data. }~ry F. Ke'llis North Engineering Transmittal # 262 DIST IB ION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY · ', ARC~ Alaska, Inc.. Post Office Box Anchorage, Alaska 99510 Telephone'907 277 5637 July 12,' 1982 Mr, C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are .monthly reports for June on these drill sites' 2 24 2'25 6-17 13-25 13-26 14-15 14-22 15-6 18-1 18-2 1E-13 1H-8 Also enclosed is a well completion report for Kuparuk 1E-12, and subsequent sundry reports for: 3-14 14-6 4-9 15-3 4-15 Eileen No. 1 11-4 NGI-7 (Since the information on the Eileen well is of a confidential nature, we would appreciate it if.you could store it in a secure area. ) Surveys for 2-22 and 13-21 are being reran; completion reports for. these wells will be submitted when .approved surveys are received. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG'llm Enclosures L 1 2 1982 Gas Cons. Commission !~nchoraga GRU1/L48 ARCO Alaska. Inc. is a subsidiary ol AllanticRichfieldCompany ,i~ ' . ' STATE OF ALASKA ALASKA C AND GAS CONSERVATION CO "'~IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling welJK~] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-77 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20749 4. Location of Well 9. Unit or Lease Name atsurface 2874' FNL, 81' FEL, Sec. 14, TION, R14E, UN Prudhoe Bay Unit 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 84' RKB ADL 28315 For the Month of. June ,1982 10. Well No. 13-22 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 0030 hfs, 05/25/82. Drld 17-1/2" hole to 2526'. Ran, cmtd & tstd 13-3/8" csg, Drld 12-1/4" hole to 3297'. POH - ]eft fish in hole; unable to recover. Dr]d sidetrack to 9462'. Ran, cmtd & tstd 9-5/8" csg. Dr]d 8-1/2" hole to 9945'. Ran logs. Cont dr]g to 9975'. Ran & cmtd 7" liner. Disp we]] to NaC1. Ran CBL. Ran 5-1/2" completion assy. Disp tbg w/diesel. Secured we]] & released rig ~ 1500 hrs, 06/12/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressur9 tests 20", 91.5#/ft, H-40 Weld, Conductor set ~ 79'. Cmtd w/2202# Poleset 13-3/8",72#/ft,L-80, BTC csg w/shoe @ 2520'. Cmtd w/2411 sx Fondu & 400 sx Permafrost 9-5/8", 47#/ft, L-80/S00-95, BTC csg w/shoe 7", 29#/ft, L-80, BTC liner f/9155'-9967'. Cmtd w/325 sx Class G. See Drilling Hi story 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SP/BHCS/CR FDC/CNL/GR/Ca] HDT, LSSL CBL 16. DST data, perforating data, shows of H2S, miscellaneous data N/A RECE .V n,, JUL ! 2 i982 Alaska Oil & Gas Cons. Commi$$ioD Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 GRU1/MR6 Submit in dupliCate DS 13-22 Drilling Hi story NU 20" Hydril & diverter. Spudded well Ia 0030 hrs, 05/25/82. Drld 17-1/2" hole to 2526'. Ran 62 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2520'. Cmtd 13-3/8" csg w/2411 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 3297'. POH. Left fish (bit-XO-MDC-NBS) = 37.97' in hole. Top fish @ 2807'+. Unable to recover. Drlg.sidetrack @ 2740'. Drld to 9462'. Ran 231 jts 9-5/8" 47#/ft, L-80 & S00-95, BTC csg w/shoe @ 9455'. Cmtd 9-5/8" csg w/500 sx Class G cmt. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 9945'. Ran DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, HDT & LSSL. Cont drlg to 9975' TD (06/08/82). Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls water, 300 sx Permafrost C, & 125 bbls Arctic Pack. Ran 20 jts 7" 29#/ft, L-80 liner f/9155'-9967'. Cmtd 7" lnr w/325 sx Class G. Drld cmt to 9924' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/9050'-9899'. Ran 5-1/2" completion assy w/tail @ 9202' & pkr @ 9129'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced tbg w/diesel. Dropped ball & set pkr. Nipple for SSSV @ 20~01. Instld tree cap & tstd to 5000 psi - ok. Secured well & released rig @ 1500 hrs, 06/12/82 JG:llm 06/29/82 GRU1/DHIO RECEIVED J U L 1 21982 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 360 Anchorage,/~,'~ka 99510 Telephone 9 ~77 5637 June 30, 1982 Reference: ARCO'DIRECTIONAL DATA D.S~~,i~,,~i 5/25/82 Single-Shot D. S. 18-1 6/7/82 Single-Shot D.S.15-6 5/16/82 Single-Shot D.g.2-24 5/22/82 Single-Shot ase sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 249 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO' MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY J U L - 8 19~T Alaska Oil & Gas Cons. Commissior~ /~ch0rag~ ARCO Alaska, Inc. is a subsidiary of AtlanticRIchfieldCompany ARCO Alaska, Inc. Post Office Anchorage, ~ ~a 99510 Telephone 907 277 5637 July 1, 1982 Reference: ARCO MAGNETIC TAPES & LISTS D. S. 13-1"'j' D. S 13-26z D. S .5-4 ~/~ D. S. 2-15~' D.S.2-1~ ..... D.S.2-24~ D. S .2-lA~/'' Do S. 13-24''~ D.S.14-17 D.S.13-2~ 6/7/82 6/19/82 6/9/82 5/22/82 5/21/82 5/20/82 6/13/82 5/10/82 5/27/82 5/13/82 6/15/82 6/16/82 Tape # 65174 Tape # 65233 Tape # 65176 Tape # ECC 1314 Tape # ECC 1315 Tape # EC'C 1310 Tape # ECC 1343 Tape # ECC 1303 Tape # ECC 1321 Tape # ECC 1299 Tape # ECC 1349 Tape # ECC 1348 ,, e sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 250 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY Alaska Oil & Gas Cons. Commission Anchorag~ ARCO Alaska, Inc. -~ , Post Office Bo. 0 Anchorage. Alaska 99510 Telephone 907 277 5637 June 8, 1982 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are monthly reports for May on these drill sites' 1-9 13-26 2-21 14-17 2-22 14-22 2-24 15-5 13-21 15,6 ~~ 1 H - 6 13-24 1E-12 Also enclosed is a well completion report for Kuparuk 1E-11. Sincerely, P. A. Van Dusen Regional Drilling Engineer PAV/JG:llm Enclosures GRU1/LI$ ARCO Alaska, Inc. is a slJb~iHiary of AttanticRichfieldCompany % STATE OF ALASKA , " ALASKA C./AND GAS CONSERVATION CO', ')llSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~]X Workover operation [] 2. Na~)op~?~O~ka, Inc 7. Permit No. · 82-77 8' Am N~)~r_20749 3'Ad~r.~ss0. BOX 360, Anchorage, AK 99510 5o- 9. Unit or Lease Name FNL, 81' FEL, Sec. 14, T10N, R14E, UM Prudhoe Bay Unit 4. Location of We,2874, at surface 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and S.erial No. 8z[' RKB I ADL 28315 For the Month of. May ,19 82 10. Well No. 13-22 11. Field and Pool ~ Prudh0e Bay Fi eld Prudhoe Bay 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0030 hrs, 05/25/82· Drld 17-1/2" hole to 2526' Ran, cmtd & tstd 13-3/8" csg.' Drld 12-1/4" hole to 3297'. P0H - left.~'sh in hole; unable to recover. Drld sidetrack to 6760' as of 05/31/82. See Drilling Hi story 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40 Weld, Conductor set @ 79' Cmtd w/2202# Poleset 13-3/8",72#/ft,L-80, BTC csg w/shoe @ 2520'. ~mtd w/2411 sx Fondu & 400 sx Permafrost C. See Drilling History 14. Coring resume and brief description None 15. Logs run and depth where run None to date. REF. EIVED ,16. DST data, perforating data, shows of H2S, miscellaneous data N/A JUN- 9 J982 Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ Area Drilling Engineer SIGNED TITLE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-~-80 GRUl/MR6 DS 13-22 Drilling History NU 20" Hydril & diverter. Spudded well @ 0030 hrs, 05/25/82. Drld 17-1/2" hole to 2526'. Ran 62 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2520'. Cmtd 13-3/8" csg w/2411 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12._5 ppg EM_W -~ok. ,Drld 12-1/4" hole to 3297'. POH. Loft~h~bi~-XO-MDC-NBS) in hole. Unable to recover. Drlg sidetrack @ 2740'. Drld to 6760' as of 05/31/82. JG:llm 06/04/82 GRU1/DHiO g CEIv£O JU v. 9 i982 Alaska Oil &AnC.~orageGaS ~ns. Co~i~aio~ MEMORA)NDUM Sta e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION -. TO: ~¢~e r~ DATE: nCh a i~~-~ FILE NO: Chat THRU: Lo'nnie C. Smith ..~ .... TELEPHONE NO: Commissioner FROM~ ~ SUBJECT: Doug Amos Petroleum Inspector May 28, 1982 108A/I · Witness the BOPE Test on ARCO's DS 13-22 Well Sec. 14, T10N, R14E, Permit NO· 82-79 on Rowan Rig 26 Thursday, May 27,..!982 - The BOPE test commenced at 2:30 p.m. and was concluded at 4:40 p.m.. There were no failures' and I filled out an A.O.G.C.C. BOPE test report which is attached. In summary, I witnessed the successful BOPE test on ARCO's DS 13-22 well. I filled out an A.O.G.C.C. BOPE test report which is attached. 02-001 A(Rev.10/79) ~&G #4 ~/81' STATE OF ALASKA ALASKA OIL & -GAS OONSERVATION CQMMISSION B .O.P.E. Ins'~ction Report :nspector 7J~u~ ~ ~s ~3erator _ ~o Well b.e, I~-Zm .._ Representative Joh~ ~ell ~,S, %~_-~Z Permit # ~3cation: Sec ~4 Tl~ba RI~6 M ~,h4, /~/$~asing Set Filling Contractor P-o_.v>k~ Rig ~ ~ Representative ~3.cation, Ceneral ~ell Sign_ 'eneral Housekeeping ~eserve pit Lig BOPE Stack %nnular Preventer /.L_ _ ~ind Rams. !/" ~oke Line Valves0( ~___ ~.~ .R. Valve v . K~I 1 Line Valves .~---~ - 2heck Valve ~Az l__ Test Pressure ACCUMULATOR SYSTEM Ful 1 Charge Pres sure, ~O~ ¢3 Pressure After Closure 155© Pump incr. clos. pres. 200 psig. psig psig min ~ sec. Full Charge Pressure Attained: ;~ min ~ sec. Cont~ls: ~ster ~. ~., Remote ~ 1~ Bj_inds_._s!4_.i..~ch cover Kelly and Floor Safety Valves Upper Kelly [ Test Pressure ~ ;~OO Lo~er Kelly_ [ Ball Type .... ~ · Inside BOP I Choke Manifold Test Pressure Test Pressure Test Pressure I Test Pressure No. Valves__ No. f !anges__ A~j ustable Chokes Hydrauically operated choke rest Results: Failures, ~Ow%R~ Test Time.' ~-- hrs.. !~ Repair or Replacement of failed cquipment to be made 'within days and Inspector/Ccmmission. office notified. , Remarks: ', ~ - Distribution orig. - AOgCCC cc -Operator cc - Supervisor Inspector ~OUOk, {J, ~,05 ~r. l~ark A, Major Area Dril liner Engineer AI~CO Alaska, Inc. P, O. Box 360 Anchorage, Alaska 99510 Prudhoe {{ay Unit DS 13-22 AR(X) Alaska, Inc. Permit No, $2-?7 5ur. Loc. Z40$tNSL, 81*WBL, Sec 14, TION, R14E, gtr~ole Loc. 2094"NSL, ~495'WEL, See 13, TION, Rl4B, Dear Mr. Major~ Enclosed is the approved application for psi'mit to drill' the above referenced we I 1 ~. Well samples and a mud log are not required. A continuous directional survey is required as per ~0 AAC 25..050(b)($)o If available, a tape containing the digitized log information shall be submitted on all lot~s for copying except experimental loi~s, velocity surveys and dipmete~ surveys. Many rivers in Alaska and their dratnaze systems have been classified as i{uportant for the spawntn{~ or ml{~ratton of anadromous fish. Operations in these areas are subject to AS 16,05o870 and the regulations promulgated.thereunder (Title 5, Alaska Administrative Code). Prior to eommenci~ operations you may be contacted bY the Habitat Coordinator's Office, Department of Fish and Came. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title 18, AlaSka Administrative Code, Chapter ?-0) and by the Federal Water Pollution Control Act, as amended. Prior to ecramencing operations you may be contacted by a representative of the Depar truant of Environment al Cones rvat ion. To aid us in scheduling field work, we would appreciate your notifying this office within 4t{ hours after the Well 'is spudded. We would also like to be notified so that a representative of the Com~,~tssion may be p~esent to witness Me. Mark A. ~/aJor Prudhoe Bay Unit DS 13-22 testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a wi tness present. Very truly yours, / C. V. Chatterton Cna t rman o f B.Y ORD. ER AlaSka 0tl and Enclosure Department of Fish ~ Ga~e, Habitat Section w/o enel. Department of //nvironmental Conservation w/o encl. CVC:be ARCO Alaska, Inc, ~ Prudhoe Bay ,-~gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 29, 1984 Mr. C. V. Chatterton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 13-6 Permit No. 81-121 DS 13-9 Permit No. 81-158 DS 13-15 Permit No. 82-157 DS 13-16 Permit No. 82-148 DS 13-17 Permit No. 82-26 DS 13-18 Permit No. 82-35 DS 13-19 Permit No. 81-180 DS 13-20 Permit No. 82-9 DS 13-21 Permit No. 82-53 i~$1.11t3-22Permit No. 82-77 DS 13-23A Permit No. 82-23 DS 13-24 Permit No. 82-65 DS 13-25 Permit No. 82-91 DS 13-32 Permit No. 82-123 In 1983, several Prudhoe Bay Unit producing wells were converted to injection as part of the Flow Station 3 Injection Project. By review of our records, we have found that intent sundry notices for these conversions were submitted, but no subsequent sundry notices were filed to confirm the conversions. Attached are subsequent sundry notices which provide formal notification of the completed injection well conversions. The dates of the first injection included for each well correspond with data previously submitted in the semiannual progress reports for the Flow Station 3 Injection Project. Very truly yours, D. F. Scheve DFS/RSS/STATE/lmi cc: Sohio Petroleum Company File 100.0 ARCO Aissks, Inc. is a Subsic~ary o! AllanticRIchftetdCompany ARCO Alaska, Inc. Post Office Bo 60 Anchorage, Alaska 99510 Telephone 907 277 5637 May 17, 1982 Mr. C. V. Chatterton Commissioner State of Alaska AIaska Oii & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBOECT: DS 13-2Z, Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill DS 15-22 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a sketch and description of the surface diverter, BOP equipment, and testing procedures; and an as-built conductor plat. Since we anticipate spudding this well approximately May 25, 1982, your prompt review of this application would be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM:3G/llm Enclosures GRU6/A~ RECEIVED MAY 1 8 1982 Alask~ 0il & Gas Cons. Gommi~ion Anchorage ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany i'~ STATE OF ALASKA '~ ALASKAO AND GAS CONSERVATION CO~,. ISSION PERMIT TO DRILL 20 AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska. ]:nc. RECEIVED' 3. Address P.0. Box 360, Anchorage. AK 99510 MAY 1 8 1982 SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~ MULTIPLE ZONE [] 4. Location of well at surface 2406'NSL. 81'WEL. Sec. 14. T10N. R14E. U~aska At top of proposed producing interval 2113'NSL. 2611'EWL. Sec 13. T10N. R14E, UH At total depth 2094'NSL, 2495'WEL, Sec 13, T10N, R14E, UM 0il & Gas Cons. Commissi~ Anchorage 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. 84' RKB, 47' Pad IADL 28315 12. Bond information (see 20 AAC 25.025) Federal Insurance Co Type Statewide Surety and/or number 8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line l-l/2 Hi NW Deadhorse miles Westline ADL28330-2495 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 9865 ' MD 9237 ' TVD feet 251 2 19. If deviated (see 20 AAC 25.050) [20. Anticipated pressures KICKOFF POINT 2600 feet. MAXIMUM HOLE ANGLE25 oI (see 20 AAC 25.035 (c) (2) 9. Unit or lease name ,Prudhoe Bay Unit 10. Well number DS 13-22 11. Field and pool Prudhoe Bay Field Prudhoe 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 13-1 We" 116' ~ surface feet 18. Approximate spud date 05/23/82 381 5 psig@_____ Surface 452n psig@~ft. TD (TVD) SIZE Hole I Casing Weight 30" ~ 20" 94# 17-1/2~ 13-3/1~ 72# 12-1/1 9-5/8 47# 8-1/2~ 7" 29# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program :ASlNG AND LINER Length Grade I CoUpling H-40 I Welde( 80' L-80 /BUTT 2463' L-80 &/BUTT 8354' S00-95/BUTT 943' L-80 /BUTT 820' SETTING DEPTH MD TOP TVD 47'1 47' 47' I I 47' 46'' 46' 8400' I 1 7911 ' 90/*5' I~ 8966' M D BOTTOM TV D 117' Ii 117' 2500' i 2500' 8400' I 7911' 9343' I 8765' 9865' II 9237' QUANTITY OF CEMENT (include stage data) 275sx PF to surf 2300sxFondu+400sx PF 500sx G 1st staqe 300ex PFI 2nd stage 400sx Class G cement ARCO Alaska, Inc. ,.proposes to directionally drill this well to 9865' MD (9237' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-3/8", 5000 psi, RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set ,above the Sadlerochit. A separate Sundry Notice will be submitted when the well is to be perforated. -23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~'~ ~ TITLE Area Drilling Engr The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud Icg required []YES ~NO []YES ~J~O Permit number Approval date Form 10401 GRUE/A4 Rev. 7-1-80 Directional Survey required I APl number WES []NO I 50-- 0 ~?- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE M~_y !9; !98~ ~ by order of the Commission Submit in triplicate I1 OF ,A, YICINITY hCA? : ........... · .. ., .. . . · " u.s.. ~ c'o.~uc~o~ UO'¢~TZOHS · · [3/19 . LON~"t~8 29 27 eG9 ELEU OF NM CORHEE OF CELLHR 90N a. 45.54 t 3/28 LFIT- ?$ t3 t5.722 LONG-149 29 26,296 , ELE~ OF Ha CORNER OF · CELLAR 90X ~ 45.Dr LRT- ~e Z3 t4,56'3 0 YIn5,932,597,15 ELEV OF CELLAR 90X m 45.53 0 MAY t 8 1982 'Nns~ 0il & Gas Cons. Commission Anchorage ~ON~m Y-5~ D~2,470.69 ~ HEHEB~ CERTIFY THAT I ~ ELEU 0F ~ ~ORflER OF PROPERLY REGISTERED AND CELLflR~ BOX 44.89 LICENSED ]0 PRACT~E ~ND SURVEYING IN THE STATE ~ . A~SKA AND THAT TH~ ~gNOTE, RFPRESENTS AN A~BUILT ~ ~ MADE BY ME, AND THAT ~ flLflS~fl ZOHE 4 DIMENSION~ AND OTHER 2. OISTflHCES RRE SU~FR ARE CORRECT AS OF: I · DEILL ' ITE' I= ,WDLL' , 19-22 A.G-I JILT LOC TIONG ": - · · . . -.:, s~.L.O~,~'~O~'~StO:l:',',: ::::.',',: ~: ::::[:::: '.~:::: .::: ,:,,'.: ',iil :iiiii!ii ii:i i!:i ::ii'ii::i i',i:~ iiii i:,:,! i!ii :: ''' ~ .......... /:~ ~ : : ~;:' ':: : ' ' ':' : : : ~ ' ' t ::::,::,:' : ; :~:, :.. 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' .....~~ ..... T~ ~ t~~ ~. ~ ~~'~ ..... ~ ........ ,,, :::: ::: ~:':: ':::I:::: :::::::~' :":: :":: :::~h'.:: ::::l:::: ::~i~l '" : iTRR6E~: ~VB=8884~T"B=94~5:BEP=~t~ :::', :~',: :::: :~'..~ :::.: :::: :.::z :::~ ::.:z::.:.'_:.:..:.~_~Lx. z2_:k:::.:,:.:X_~:z'. ~:-::t-: .~---~--~ - a~-C~T...!v~gioI!~'~I5 t::: '~ :4 :.: J.: ;.: :.L:~, .: :.z::: ::4 ~-:;::-. -: ~ ~Ti~ ~6~:.;-: -:.:.L :.2:: .... : ~ :.:_. j . :.~.::: J z::. 1 :-: '.-~-t .... '-: l: :- J-.: i '' 1 .... i .... I .... ~. :4.; ~ :.%:.t zL:; :-:4-1 1::; ~::::!':" :::'::::; :::t:::: ':: ,':',:,:,:.t::: I:::: 7~:: '::' ! ' ':::1:~: !':::l-::t::'.l 'I.. I : !'::'1 :t:"~: ~:;'!~:: :::~t:::: ANNULAR PREVENTER BLIND RAMS PIPE RAMS SPOOL PIPE RAMS RECEIVED IVIAY 1 8 i9B 0ii & Gas Cons. Commissmn Anchorsge 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test 5. 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 simultane- ously and record the time and pressure remaining after all units are closed with charging pump. 4. Record on IADC 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 a non-freezing liquid. -~ 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a 250 psi low pressure test for a minimum of ,3 minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams..~ Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. g. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe rams. 11. Back off running Joint bnd pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. .14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. Rev o 3/12/81 SURFACE i HOLE D IVERTER ARCO ALASKA SYSTEM INC'. · .' , SCHEMATIC I0" HYD. OPR. BALL VALVE .,,/.,,....--WELL BORE (SEE DETAIL) I O" HYD. OPR. BALL VALVE I ALL 90° TURNS ARE "TEE" CUSHION ! ~LL QBORE RESERVE PIT AREA NOTE: FLOWL INE DR ILL lNG R I SER · 2O" 2000 PSI WP ANNULAR PREVENTO~ ',,. I 1 F'J ~lO" HYDRAULIC ~~"~ I0" DIVERTER LINE ~ ~ Valves on diverter lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PZPE "DETAIL" 2026010203 CHECK LIST EOR NEW WELL PERMITS Company ITeM (1) Fee (2) Loc (3) Admin APPROVE DATE L_.. b ;/~'~X--'2''''' 62~ thru 8) 3 4 5 6 7 8 thru 11) (4) Casg ~~ ~5~7~-'~'Z- 12 ~f~_ thru 20) 13 · 14 15 16 17 18 19 20 (5) BOPE ~.~'~.~f-~- ~1 thru 24) 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 .... 1.1.~111111~. . 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 ........................ YES NO 9. Does operator have a bond in force .................................. 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ................................... · Is conductor string provided . ...................................... · Is enough cement used to circulate on conductor and surface ..... .~ diat iii'~;'~' .~ Will cement tie in surface and interme e or production strings · Will cement cover all known productive horizons ..... . ........... · Will surface casing protect fresh water zones ......... · ......... __ · Will all. casing give adequate safety in collapse, tension and burst· .~ · 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 ........................... ~ _ 21. Is a diverter system required ...................... ................. 22. Are necessary diagrams of diverter and BOP equipment attached ....... 23 Does BOPE haVe sufficient pressure rating -Test to 5¢~'O psig ..~,-~__ 24. Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. (6) Add: ~ ,~"~"g~'~ 25 Additional requirements ............................................. Additional Remarks: R~IARKS Geology: Engi~ring WVA JKT ~RAD JAL~MTM ? · rev: 01/13/82 iNiTiAL 'GEo.' UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,,, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. '):,2 :::,E A R("H A I~,,GLE 9476.0 7.4 5 1~9 70 948a.0 10.I t7 I2.6 74 9490.0 10.2 31 12.6 9494.0 6.j 2~5 12,6 9496,0 1.6 6 12.7 42 9500.0 0.5 {95 12.~ 1~2 10o2 950~.0 1o0 163 I2.8 ~ 10,2 9504.0 0.9 9.7 12.~ ~2 10..~ 9506.0 J.6 59 12.$ 95.08.0 ~..~ 27 I~.? 32 10.3 9510,0 ],I }5~ I2.7 32 10.2 95I~.0 4.~ 254 t2.7 3~ 10.1 95i6.0 2.4 1~8 12,6 9526,0 7.7 212 12,6 ~2 9,6 ~5)2,0 12,6 {2 9,4 9514.0 4.1 2]7 12,6 32 9536.0 5,~ 252 ~2,6 32 9546.o 4,9 ~I~ 12.4 9550.o 2.g 40 12.3 3.2 ~.5 9,9 I0.I 10.2 10.,~ 10.2 10ol l,O,O 10.0 g,9 9,5 9.4 9,2 ~56~,0 12,1 ~4 g,6 8:'5 * 9596.0 16.5 ~0 12.0 77 8,'~: B*6 B 95~,'0 ~.i 251 1.2.,0 77 8.6 B.6 D 9600.0 6~.'5 2~ i2o0 76 8,6 ~,q O 960g.0 1.7 100 I]'.9 76 8'6 ~,'7 ~ * 9614,0 4.6 2a li.B 75 ~,6 8,7 9616,0 6.~ ~57 I1,~ 74 ~,6 $,7 C 96i~,.0 ],4 ]2! 11.8 79 8.6 ~,7 A 96~0,0 4,4 342 I1.8 71 8.7 8.7 t * 962~.0 6.1 342 ii-,7 72 8.6 8,7 9624,0 ].i 324 11,7 72 8,5 8.7 i 9626.0 4.8 ]47' 11,6 71 8,5 8,7 96~0.0 ].9 42 tl.5 7~ ~,~ 9,0 A * 9650.0 ~,1 t24 11,:4 * 965~..0 * 9660,.0 5 * 966~,0 1,1,5 m 966~,0 II.,5 ~ 9670,0 * 9676,0 * 9680,0 l,l 55 It,4 * 96~2,0 11,4 * 9694,0 * 969~o0 * 969~,0 11o4 a 970~,n 7,5 {77 11,4 * 0704,0 11,3 * 9706.0 4.~ ]40 II.3 * 9710,0 ATLI~TIC ~I~IELD CO,PA O~Ibl. SITE 13'22 PAGE , · AZ't, * ~.~I, I-~ '2-~ 9712,0 * 9714,0 * 9716,0 * 9?20,0 * 9724,0 * 97~6,O * 9740,0 * 9742,0 * 97.46,0 * 9758,0 , 9~62,0 * 9.764,0 * 0766°0 * 9768,0 * 9770,0 * 97~6,0 * 9784,0 078~o0 , 9788.0 , 9790°0 2,~ 269 11,4 4', I 1~ 1 1o8 i*~i .7 ,-0 20t 11 ,.1 1, ~ 285 1.1,4 '2,0 299 11,4 1.9 1~ 11,4 5.7 ! 1.$ I 1,3 11 ', 1 t 17 11. 11 8.6 77 11,1 0,5 ]56 5:,4 t51 I1',~ 2.6 248 2.8 227 11,4 5,0 2~2 11,4 6,1 166 11,4 I4,6 57 ll,4 It,4 66 11,4 12,2 61 11.4 16,4 72 11,5 9~06,'0 7,'~ {'50 Ii,$ 9~0~,.0 .0,~ ti2 i.I,5 .~14,0 .i.2,2 i.'gl 9.:.~. ,/0 5,7 tt'2 ti.,.5 9~0,0 {"0 ilo 9~]~j0 4,.~ 1~ 11'$ 9~4~',0 1.1,5 9~46,0 5,~ 329 9~5~.0 tl,4 9~54,0 10,2' 90 1t,4 9~56,0 10,8 17~ 11,4 9558,0 Jl,4 9~60,0 1.0,5 t47 1.1,4 9R82,0 lO,~ 1~ 11,4 9~64,0 8,~ i94 qR66,0 8,5 114 1t,5 9~6~,0 6.q 195 11,5 0~70,0 7,1 2ti 11,5 ************************************************************************* * 0884,0 ~,9 243 ~1,5 , 9g~4.0 15.~ 22.~ I1.5 , 9~'96.~ I1,4 217 II.5 * 989~.0 16,t 1~9 11,4 '* 990~.0 {0,'] i~8 11.4 ~ ~o04.0 ll,l * 99.06,0 I1,~ * O010.O * 9912.0 11.0 © 12.3 tl 7 0 ? © © # 955S.1~7 12.3 60 e 74 i74 252 0 i2.2 ~4 ;~ ? ? 7 7 ? ,,.6 6 · ? 7 0 0 © CiJP{ Ctl~2 Ct{P3 CU~4 a 7? :~7 ~ 12.0 6,4 ~,~ 12.0 7? ~t Q t7 7~ 9 5 ~ 0 6 6 0 ~7 3.? 236 ~.~ 274 5 7 7 © © 264 0 ,1t..] ~70 ,~ '2 0 246 O { 1'.4 7-1 B 2 4 © · 97~5.25 269 ,6O t e © © ~ CU~! CU~2 C~ 3 CU~4 ~ 97 0 0 O 0 u 0 11.4 Il ,.4 ii.4 ilo4 1'1.4 7 0 ? 7 7 7 ? 7 ? 7 ? ? ? ? © 0 7 0 0 0 7 '5 O ~{O,4a 24,1 28T 0 11.5 © ? © 10.5 209 25.0 Jii ,2 0 0~0 0~0 0'..0 L , oo[! ooo oo a -6o0 -0oo 0o'2 ~ -, - 00,'.:~ 000 012 ¢ ~ '.'¢ · -¢ - ': ¢ '- - ¢ 000 000 006 CTRY: U,$.A, : :. . CODE 065 065 005 065 O65 065 065 065 C 0 0 E = ~77 ~ ~9~ D~ A~t APl AP], ~P1 Et,~g $tZc~ PROC.ESS ,SA~ PLE LOG TYPE CLASS' MOD t~'O, LEVEI, ET 0 O - 0 0 0 ,4 0 I 0~ 7 0 0 - 0 0 4. 0 1 ?V 7 t O O 0 ~ . 0 1 GAFI 7 3i 32 0 0 4 0 1 pu ~ e~a 2 o o - ~ o ~/c~ A~ ~S ' i o -o 4 ' o GlPt 42 31 32 0 0 4 . ? 1 t~~ 4~ 2~ 3 O 0 4 0 G/C3 1 2 &~ 9 2 _ 0 0 4 0 ~42" 24 93 O O 4 0 REPR CODE 68 68 68 68 68 68 68 68 68 6~ LVP OIO.MO1 VERIFICATION i:ISTING ~--~uc, ~, 5P '79.5625 GR 26"R~25 DT 9~.1~7b u~ 26.8125 DP~] -~9~.~500 ~PNI -:999,2500. G~ -999,2~D00 t~tR~, -999.2500 DEFTs~, '79~0t25 GR ~3,':1562 I~T 9z.1~75 G'~' D~HO 0.0171 NFAT 2.6875 ~-: C~ b 3380.0000 FCNL NCNB -q99,2509 FCNb ~ -~99'25(;'0 DT g~-o~5o 1.9160 23,1562 ~,4063 ~i64.0000 -999.2500 84.5000 ~.4531 1 .7188 5859 227 ~0000 -99~ ~00 69: 50 DF~pT 97~,'O. ;~000 ~FBU t7,~19 ILr~ - 12,{~:~9.- ~D 16.6094 ~ ~ ~ ~ ~. 25{'3 <;~ ~21-56~5 PT 96,~875 G, 22.5625 · ~ ~<,.~".= ~c~ ~ ~o6~ ~;.~ zs,~ ~: 71o9 DbY -n;O015 ~-~ p AT 2;7500 ~;3CN b 3334,0000 ~CNb 113.000O ~b '99'9;2500- FC~JL _ -999,25o0 [>T 94,5000 UTI, 93 5000 -~ ................ ~ .... ~' '~ ' ':~9 ill> SP -06'7!z5 GP 23.2'~ E, 7 ~T 97. b*%~ ~' 23. 87 ND~I 2e.0742 ~.HO~ 2,-2598 {j~P 26,1-6~75 CABI _ ~,789! ~ ' '25~0625 G~ 98~t. 25 DT 8~562b t~P" NPHI 2~.2~76 R~O~ 2.609~ GR; 93.~625 C~bI DPMi 2.4.~ 4 NP~t -999.2500 D..t,P'~ 94{)C~. 0000 SFLO -999. 2500 ' 6,91~1 98.~125 10 1484 1440: . 000n -99~.2500 999.250u -,'9~9.2soo D~:PT ~ O0,OnO0 SFLU ~q~9,2500 I-t.M -999,250Q ILO -999.2500 ~' -aqq:25¢)O NP~t 55,4688 GR -62-,0938_ N~AT __~ 4453 DP,,I DEPm ~{~00. aO0{~ SPI,U -9a<~, 2~u{~ 'Ib~ 999.2590 ILD -999.2500 '*~ -g99,2500 - : - :- -'. n~" ' "~'.Ou(>~ ~'..~, - g~ Z~O0 1-[,~~:, 9.~..~,2;~-0v ~p[, :::. ,250, c~" ' .a~<'~ 2~00 GR ~9~¢~;:2~0o ;::, -999.2500 GR ~99.2500 {'~ PHl -gq,:~ ~ 2 gO()- k~iO~ -999,2500 GA -999,25.00 CA~I -999.2500 DP~I -999,2.500 ~,~P~ I 49,2~-~7 ~f~ :- _9~.87.50 ~.RA :I' 4,~016 S' ~P~ ...... .... -' ':~-9 "~:~:.~x" ."':.~] ..... U~ : '999':" :;"~';:':":Z~;O(;': ?'"'i.)~ -999. '~ "'2:400 dR -q99,2500. ..... ~ , .. ... ~ ¢~ ~. , ,- - -~ -.~4~ ", ~ ( t ~ ~':' ~'~ ' * ,250 0'~0 . ,- ......................... - D~H:I: -:~9,.,, ~ ~Oa :,¢Fh~ 47,~09S Gx _ 6~,6~:75 ~RA! 4,0078 ~'~r, ,~.~'oh~,6 ~,r~{, ¢~.d¢.7:~00 -f:,T -999;~500' D:~t, -999.2500 GR,, . -ga9.2500 : - . bvP O].O,HO1 VERiFICD. TI[}~'~ LIST£r,.;L4 " C_N 1. . .. 2500 - 0.- 9. 9 ] '?, 25U0 999 2500 <-~ e <:~ ' 2500 -. _:., , ~999.25V0 - 9~ 9.2 ....:~ ~ ~ - q 99: 2 S o 0 .25v .., 1999 ' "0 F(.ML '909.25.,0 500 3,7656 : 999.2 s o o 9 g 9.2 50 0 ~ 9 ~, 2500 'g99.2500 -'999~ g991 ~500 ~ '~ f~D -999,2500 :R -g99. 2500 GAb .999. 2500 - 999.250 C 6~5 i'RAT 4.0547 9%0O ['T!; -999. 2500 - 9 9 9 Z 5 0 0 ~ -9~9:25oo 9~,~500 i -999,2500 "999 ~ 2500 ~ 3 37 7 o 2500 DT5 '999: 2500 .~o~.~:~:,.:. 2500 ~I,~ -999,2b00 i. LD :q99,2500999' 2500 -9q9, ~00 Pq" ' '999,2500 GR -999 2500 GIR -999,2.~00 CALl 999,2500 -609 .... : 2500 :f?Ct)t. -~99. 2500 PCNL : 999.2500 l 345,5000 ~SW '99~; 250() DTL -~ · -99~,~500 iLD 999 2500 '999~2500 G~ ~99912500 -999,2500 C~Lt -999,2500 -~o9.2500 FC[~L -999.2500 a~2.724.~ G~ 54,7500 f:RAT 3,7461 .3i7500 [:)~' -999~2500 [)TI .... 999,~500 -qqg.2bO0 G~:: 999.~UJ 40 9t b(; 6[; 53.90:62 ~<RAT 5 ']~: ~000 [2,~' -999, ~500 DTL -999,2500 '999. 2500 -999. 2500 -999 · 2500 3,64~4 -999,2500 -999.2500 -999.2500 -99~ 2500 ~457 -9~ ' 2500 · O~P% 79<~0,0(~o0 8FLU ~qgq,250© fLN -.999 ~500 IbD -999 2500 NPH -9c~. 2-500 RSOa~ ~999,2500 GR ,999~2500 CALl -99~.2500 OEP'{' 7~0D.0009 ~ F t,., U ~99~.~500 i.L~ -999.2 LO() ibD -999 2500 ,: ' 9 9 25~ M( ~OO ~, 99.2 0 C L .............. ~OO D'T-, -99 0 . t)~iPT 7"60_i)oo0 ~" ~; ~}'~ 5<,0 {-- -99~ zBD,) I 2500 NEVI ~999.2500 RH[~b ~999 .-~500 GF'. ~9:99.~500 CAbI -999,2500 !.77e'0000 ~<l:t~L 4!4.500o OT -999.2~00 OTb -999~2500 : . { ~' I " -999 2500 NE-HI -999,2500 a~lOS -999,2::500 {i~ : -99-9.2500 CALl -999 2500 DPHO ~999;250(J ~.)RAT "999;2500 ~-)CN L "999.2~00 FCNL -999:2500 -999.2500 -999,2500 2500 0039 -999;2500 -999,2500 -999,2500 -q99 0 SsooO GYP 01o. HoI p GP ©F ET ~F .. 0'4 H .. KP't' 7t00 s; ::,, ', -,, ' 655 3~9.2590 f'~:? .9o9, 2~;00 P!~b 2500 7793 999,2500 491.0000 4.0039 -999.2500 -999.2500 -999.2500 999.2500 999.2500 3.748o -999.2500 -~., 9.25oo 999. 2500 -99 25O0 4 0781 -~9912500 :999,2500 999.250o -999.2500 -999.25on 3.4824 -999.25oo :~99.25o0 99.2500 -999.25uo -99~.2500 ~.8770 -999,2500 -99~,2500 -999.2500 :99~ 2500 4.0703 -o99,~500 -~'"- ¢99.2500 -999.2500 -999.2500 -999.2500 3 578I -999:2500 -999.2500 -999.2500 ~tr~]6r:,.{.]~ -ggg,250Q" F:~O~ ~999,2~0~> ..........a~ ~999.2500 CAbin. -Qgg, 2500 ~ ~99; 250~ GP .gqq ~ 2500 OT : 'ggg' 2500 GR -999. 2500 ~P~} I -g~c:. 25(}0 ~ {~ [3 ;<~ -9-9q. 2~00, C;R . -g99. 2500 CALl -999.2500 '~PP~ -9~.z~O 5~ 45.0t95 ~... 34,4~:~8 ,~RAT __~.8739 ~'~ C ~,~ b I 5t.~O. OuO0 PC~.'L 357.9000 D'P -999,2500 DID -999'2500 G~ -999.2500 : _ ; SP *099.25C)0 GR ~999,2500 DT *gg:~) ,2500 GR -999,2500 DaF~C~ -'~99.250u ,,f~ ~?: -gvg.~SbO NC~,[, -999.2500 FCNL '999.2500 'qt'{L ~.~6j,OoO0 ~'C~,~I, '4~;2~00' - -999,~500 OTL '~99~2500 ~. , ~ . ~ , . qo ~ -~ ..... ~ 2-500 tod -997;', 2500 GR ~9q9. 2500 :PT "999.2500 -999,2500 R~08 ~999,2500 G:~ -99-9,2~00 CALI h~,,, ~' "~,', n" ' --.~ ~-..- ,0:' 2500 YJTL .~-,~Ov . C,~,.~ 5 7.7560 ~,~ -9 2500 ,OOO0 SFLb -999.2500 i~ -999 ~6 o ~ (~ ° (:-~; 2 ~:~ 00 t'~ ~A T ~ qq9.2'5 00: ~ C~ L -9o9.~ 500 FC~ -gaa.~O,~ ¢~oF~I 40 t~b7 G~ ~'i 8t25 ,.k. ~ %¢ , : ~' ~ { e~ 4- ~ ~ - ¢ -'¢ ~ ¢~ ' ¢' --- ~- , -~ ¢ - .... , - %999,2500 999,2500 -999 2500 -~9: 2500 3.220? -ggg.2500 -99 .2500 ..2500 999250u 99g%2500 3.b055 -g99~2500 2.~0 u CAb -9o'q.25o0 ~C~'~b -999.2500 FCNh 372,5000 DT -999. 2500 DTL -9~q 2qhO iL.A -9;}9. 2509 _~ l': ,-' . ~ ...,. tt -~ .. 2 -' * . ,,. ~- -- %' . 42,~7~ ~,~ -45~563 NRAT . sOO -999.2500 -9~9.2500 ;9¢ . 5oo 999.2500 4.0508 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.7402 -999.2500 ~V'P O.lO.M01 VERIFICATIO~-~ LISTING ~'at,~.~ ~.u 5~ ga ~, 2 .... J _,~ ...... ~ ..... , .-~. ..... , ....... ~nn ~?~- . a 5 0 C~LI -999,2500 ;q~' 5AO0 o00o ~5~L~ -q~, 2500 "[ ~ ;'~ -999,2500 %bD -99~,~500 '~HI -~o~,2~qO :';;0~" -9~.~,2~0 -GP · --gqg,-PSO0. CALl -999 2500 2 _.~t>.- -,, a ~..., ..., ~...~(~.~. r,.~.. -9~9,25 ,,t ).,T 999,2, ¢ ..... ,.~a~, 2~00 ~HO~ -9<~,2~00 GR -999,2500 CALl -99~,2500 g~ -999,2500 . . .. _. - "'_ : ~.;~:~-~,.,, ~:,o,c,:ooo sF'~,',.~ -~,~.~0 ~fE'~' : '~'~::~ ~? -9~9 2500 SP ~(~9.2500 G? .qa~90'9'2500 ~>'.r -999,250o'~;'~'z'"uu CALI~'~ -999' - , .... -'~ '~' 4 '875 ~ -gqq. 2500 . . u~.~ ~. ~ ~-~ nqnr o-~-.,~. .aa6 9~on TI ~: -q99.250Q iLD 56 ~ ~oC, ' '2 5 0 ~", r:Y~ '9Q9. 2500 DT -999.z~00 GR ~P~ I ~:~c~, :; B<:O R~i'~¢ ,999.2500 Ga -999.2500 ~AbI · ~ C a ~, , ,,~. ,, . 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SP · - <~ <~'~ 25{)0 t-.~k~ ~ ~'6, O25,~ G-R ]2.7813 ~AT b.57~2 4~0{J (}<,,00 SFi.-U -c~9 2500 t[.~?~ -999,2500 ILD -~99,2500 -~o~[2500 Q~' ~6f~ 250n DT -999.2500 GE -999.2500 . .......' .... . ..... ~t~O ~ -99~,~00 C~L~ -999,2500 '9~9 ~500 *'.~ ~ ~ ? ~99,2500 ~*;'C t~ L '999;2500 FCNL -909.2500 3.~ 0000 vCF~!, 3~7: ' 2500 C'T ~999 ~2500 9TL -99 2500 4;s~O 00~,~ ~FL5 ::999, -999 2500 'bS,().~[~[~ G~ '9~9,2~()0 ~:% -999 ;:~.50n (;R -999.2500 -~99 2500 ~ Ht.}b -999,2500 O~:. -999,2500 dALi -999.2500 -666~'500 ~:RAT '999.2500 ~.:CN f. -999,2g00 FCNL -~g9.2500 - ~<~',~, 25{:, 0 f':: F'H ? 48 0469 (~.~ 2~. ~, ::~94 :~RAT ~.0352 i ~ J;~ [ 00(.:,0 FC?.~ ' 3~,50(:0 PT -999:2~e0 DTb -999.2500 -999,2500 4,~ (~O, 0 r~'~a 5FLU -999 250() tb{'4 -999,250'O ~LD -999.2500 2666;2~:~;:~ ~: ' '~0;250° DT --g99,2500 GR -999,2500 -999 2~00 RHOb -99¢~ ~'' ................ "~ .... ' 2500 -666.2500 ~4eAT -~¢;2500 !'~ C ?'~ I., ~999/2500 FCNL -999.2500 ,,~ '~:Oa :*~PHI 49 g. lb7 G~ 36,6~0 r~Ra.( 1016 i~09,0o00 FC~f .... 359'~;~0.~, .~. 6T, ....... ~999i2~00__. ..... DTL -99 [2500 4300.000t) 8YI,{.~ -999 '~("~' ~''' -ggg 2~00 iLD -999 2500 r,,;,,, ~'~,0 ,';~ '~9 2500 DT -999.2500 (,R -99912500 - t:' ~9.2~ 0~.~ ~ ;~ O ~;, -~o9 2500 GR -9-99. 2500 CALl -999.2500 -90c~.2500 *¢ ;~ ~.:f' -6i~,: 2500 ~<~C ~ [., -999/2500 FCNL -999.2500 -999.~¢0u ~:,-~,~','~"l ~ 9727 G~ 16,2.9~1 ?~RAT 3.9805 -' ~{:) (~ ~;~ --~; 2~fJ OTb -999: 2500 197!, 0{h0d PC~ 13 498 .................. -999.25(;0 ~,-.., . ,", , - ~ ~ 0 , -999 2500 ~:., ¢ .~ I, .... 9.. , . .......... .. ., · '6~912~00 ~ .9q(~.o~0o n~'. -o9~ '~:"O cR .qoq 2500 -99<~ 2500 R~[38 -999,~50[~ Ga , -999.2500 CALl -999,2500 ~66~{~* 2500 {,~'AT -~9 ~ 2500 N-CNL '999 i 2500 FCNL -999. 2500 -999,25(J0 ~,4P.Hi, 49,4',.,i~1 GR 40,4375 ~;~RAT 4.1133 i ¢.~6 [ 6()O6 FC~,! 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Opb,'l -9<:~q,2500. ~Pbl 66,~55! 6~- '999~' 17 219 NAAT ......... ~ ...... :~ ::'- .... ....... · 500 DTL NPNf, 151;1~.0000 F'Ct~L 735,7500 Dc ' ~-:, 94~,_b000 SFt'~i{ -gg9.2500 IDN -999,2-500 lbo DP~I' -c¢~c¢, ~ ~{30 ~,, P~ I 59,32e2 .G~ 19,-1 ~06 HRAT -999.2500 -999.2500 -999 2500 -o~9:2500 4.550~ -qg9,2500 -99 25OO -999.2500 '999.~500 .99~ '°~9 .2500 -999.250o -999.2500 -99~.2500 -9o .2500 4 ~5~3 -q99~25.00 LIBkARY CURVE SPECIFICATIONS Company ARCO ALASKA, INC.. Well D. S. 13-22 Field PRUDHOE BAY County, State N. SLOPE, ALASKA Date 6-15r82 Curve ~ame (Abbrev.) Standard Curve l~ame ~ogs ~3sed GR1 G~mma Ray Pass 1 'iCN-Multispaced i 0-i00, 100-200 GR2 " " " 2 " '~-, ',' '.," .. CCL1 Casing. Collar LoCator Pass 1 " 2050'-50 CCL2 " " " "' 2 " " SSN1 Short Space Neutron Pass 1 " 45-545 "~ _ SSN2 " " " " 2 , ' " " LSN1 Long Space Neutron Pass 1 " .0-400 ! LSN2 " " " " 2 " " CN1 Compensated Neutron Pass 1 " 60 - 0 ~ CN2 " " " 2 " " , ' . 5.' '" .............. ..... ~ ~ I .... ' ~ ~u- ' "" .... ' ,,, , , ~ ,,, , ,,, ,,, ECC NUMBER ARCO ALASKA INC. -~o '-CURVES LEVEL SPACING 0,5000 PAGE ~RCO ALASKA INC. _. D E P T_H ........ .G_R_ ........................ _G _R._ ................. _S_S_N_ ....................... sSN... ........................ _.L_._.S_N_ ................. L...S_N_. ................. ._C_N_ .................. C_~ ............................ ~__FT_: .............._.~_P._Z_ ................ _A..B~ ....................... PAS.S_..__~ .......... _P._A.S__S_.__2 ....... _e_AS_S.i ......... P_.A_S_S_.._e_ ....................... ~_ ........................................... ~ _ PASS 1 PASS 2 ............................................... R..A.._.S_.._S.__.~ ................ ~.ASS .__.2_ 9025. 5',7 138 0 8 62 4 9 9045. 48,5 50.6 137 8 1.30 8 58,1 54 8 49 9 9065. 55.3 54,6 1.28,8 136.0 56,0 60,9 46,7 4~.8 ~.~ 9085. 59.6 45.5 118.0 ~'~4.9 55.8 63.2 ~ 9105, 39.0 54.~ 158.7 1 33.~ 63,4 58,1 55,6 9125. 62,2 55,5 105.~ 127,2 50,2 55.2 58.8 9145. 9l 65 40.2 40.0 160.9 158.2 66,0 65,5 52.7 59.0 65, ~9.0 4r~.5 57,.6 9205. 53 5~ · 9225. 51, 57.8 3¢J.9 53, 55.6 138,8 1.45.0 63,1 ................. ............... ............................ .................................. 9465. 54.3 50.3 208 6! 45 8 63 4 243 9 114 179 7 53 3 PAGE ~RCO ALASKA INC, ) · S~_i 3- 22 DEPTH GR GR SSN sSN LSN LSN CN CN FT, A P ! AP _ PASS I P_ SA~_ 2__ 9505. 8 !gLO.6 193 9 17! 2 7 26 ~ 70 I 5~ I ~38 5 P12 1 I 95~5, 79,6 8~,~ 26~ ~ 185.3 185 9 10 ~ 19 3 9565. 52.8 90,0 217.3 31~.2 151 9 2~9.7 25 5 6 9585. 5'/,6 60,9 221. g,~ 30q', 25 136,5 2q'l+ ~,~ 6 2LI', ~ 9605. 27.q. 115.6 201,2 197"9 1~. 9 11,5.8 9625. 32.6 28.A ~28~ ~23'1 1~0~6 135,6 96~5. 30 9 ' 25 9665. 30, ~ ~ 8 1:55 5 9685, 29, 7 9705, 29 9725. 38 97~5. ~5 9805. 31.2 27.7 225,9 ~05,2 ``"=`"``~=~;~;===~;~`~=~`=~`~="`~=~;~`:;~`==~``~``~;.~`~`~`~`~=~`~=~<~<~`~== ~,~<=~,~.,....~.~=.~.~=~=~,~.,~...,.~.~.~.~=.~.=<~=,=~.,=.~=:~.,.~ ..~..:~,~.~,:=,~..=,~....,~.~..~.~_..,,.~.,.~. ......................... ................................................................................................................................................................................................ 9865. 3~.5 ~5.0 206,2 9905, ~2.9 20,3 !56,9 9925, 0.0 22,1 0.0 200,0 0.0 ............. ~ ..................................... ..,:~.. ................. ....................................... 99~5, 0,0 38,3 0,0 i97,1 0,0 10~5 0,0 3~, 0
