Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
201-063
STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well El Re-enter Susp Well 0 Other:Set QCCL Patch I1 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 201-063 3. Address: P.O.Box 196612 Anchorage, Development B Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22410-01-00 7. Property Designation(Lease Number): ADL 0034629 8. Well Name and Number: NIA NK-07A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,NIAKUK OIL 11.Present Well Condition Summary: Total Depth: measured 18512 feet Plugs measured feet RECEIVED true vertical 9589 feet Junk measured feet MAR Dp Effective Depth: measured 18384 feet Packer MAR 0 7 2016 measured See Attachment feet true vertical 9490 feet Packer true vertical See Attachment feet G CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 33-113 33-113 1530 520 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 12701 9-5/8"47#NT-80 30-12731 30-7333 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 17710-17830 feet 17940-18085 feet True vertical depth: 9061-9126 feet feet 9190-9281 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 28-12671 28-7302 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"HES TRSSSV 2042 1986 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: fitiEV (.i , ( ,°, h, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 286 180 4309 2069 874 Subsequent to operation: Shut-In 20 1980 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development ll Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature C Z Phone +1 907 564 4424 Date 3/7/16 Form 10-404 Revised 5/2015 31i//f03A/4RBDMS MAR 0 9 2016 Submit Original Only • Packers and SSV's Attachment NIA NK-07A SW Name Type MD TVD Depscription NK-07A SSSV 2041.94 1985.81 4-1/2" HES TRSSSV NK-07A PACKER 12094 7029.58 3-1/2" Baker 45 KB Packer NK-07A TBG PACKER 12613.7 7273.45 4-1/2" Baker S-3 Perm Packer NK-07A PACKER 12616 7274.6 3-1/2" Baker 45 KB Packer • i g O O cu O O O O O O O D N (V (N V ci op co co U 0 L co0 0 0 0 OV O co O co IO V coco cics) c) CO M 0000 CO • I- O CO O N O N CO CO CO I- O CO 00 O I� M N M N O C1 1 1 1 1 1 1 1 1 1 H N• O r- V V M co I- O O (NI co N- O 00 CO CO N- CY) O N N CO N CO V f— N- N- CO 00 N- C (O 00 M N CO I - CO O N- E 00 0 CO CO M 0 (O - 0 0 0 N N N N CO N V QM 00cor- V o co co O V O 0 g N" 00 a) coco M 00 M N N N N = Lou, _• Q Z O O O O O O O O O 00 00 00 00 CO CO CO CO J J J J JCO k *k Z • CD CO N CO O Co CO • N -# O N O N- CO *k `- N Cn O 00 QO V CC/ N O r- U O M co c`) co N - CO N N r O) M (..1 V V 0 CV O CV O V M C 00 co O co N O co (O O O O < N J W OOQQZ Z w c W W W W W m OJJJ ' ZZZZD 0 w w (n Z J J J J H • 0 _ 2 ai a)iii p Y s c EF- `- EN) ) c o E z E 1 n D N O cu 0 C N U Z 0 o c E 1- -J C L11 ;- E 2 z a E Z (� 0 a) a) 0 _c LU (n c6 c U W C 0 0 0 V. �O O 2 2 p N Q c6 N LO w2 (a Q mco J m H 0 CD a)a) 0 � 0 U c O O � N m a) f- ccO � Nr v0 N E NN � N 0 w c2 - () Ns 2Lo 2 � ©© N ~ a mm N o > U M -1 N W W = N -J a O0o 22 c`a as o) o' (n < .jd N � F- Co W � � Lam c � U - u U) a Q o a) Q D ` 2 2 am W � ami � a m � cj -= > > ,O _(- 0 Le 7-1 12 > > c = CV 2 L wQ a) S EeL(n � ``� Oco a)wU � EQ � �, � � w � o d > m (7, 2 , - aD 2 `� 10 � � 1X J �(' Eo = 0 ._. J ri a D510 =1 u) m (O � Uv ZN F- F- W -I. SCC C ct 76 Y% or) � � U0p pZ 0m m < 2 ,501- 4- J J Hw 4.1- Z n V U (no co . z F- 5 z � : o2F- Nzz om 2m Zm t a 0IO00Z mow N 0 w0 WpZ cin mz O �� Q� � 2 00 * � F- w Q ¢ Qp `� Z � IX W aa * Lc)* 0- * `aa as et + a F- z ,- N _m J J J U I- <- 0\D Q co U J a'co W Lo N O L M O c a. O ^O >+ Qat Z > � ,- JQ Da b0 oNd F- pl- Q - c\JCO ,- � M EHE" c ,- > Q2 . pN om (Aa aoz `\ - mUa_ Owmc\ � x ._v x mz x m co E W 2 0 Q 2 Ln a w z M J c a' F- m a N O N N 0 U Q p E N 0 Q O M W J m ' c J m Q C7 W = O ,- J ,- a) < 00 0ZZ � 2 ow wmzz fxQWo6K mz /x — _ z � � Om (� _ ZsOai= a U D0QOaaOW JOaOa � aOa > m0 > op z W Cn 1n Ct (n F- (n io 0O a � (�n (�nU � W9 mmc~n (a) moQa , Q (Dw (nZpwmZ 0-QZ mm cn - X20 - 5 > - X DQ � Nomo1- c, 2awx - -• Et � � " cr cr � wCCN • -icon - oov1- F- � o - wcn ,- w WF- F- acZma XF- F- ,_ a)) F- H (N zta (N a)iF- WZz rmmoom - YQ2 � ZZ000w `' UJw � 00 - > 00 - 8w w > O > QQ .c < QUUQQ co < 1NQQWWUUF- < DH < UQ 0UUQ � i- Q ° U * a' CC a' a' * * a' a' E 2 m a- a' o_ 53: * < a. * * 2 T : # 2 :_--< 2 2 W Q Lo Q = Lo L() In r >-- N N O O O F- O N N N 5 N N N M ~ ,- N 0 Q • 110 U) C 0 0 b a) (') c � a ) U) 2 E c p O _c rn _ - Lo p)b J a) p J L p c U) LL L D a) -o cow 46 E I- Lo as _y N L O N U N O) O D O E a) a) Ln +s Q J NO O N IC) Q E a)U) O F- r N O O O -a N a. E a) p O >Z j p U +�d a) U) c ❑ O V7 ([�� C L �C & ,pct O N 0 as v E E 0) o W ❑ ` _J c L O N CU a- CO N m 0 Q O * a) -ii3 co O < U) U)LL- c 0)* U U NYU) © a) J 2 2 ' 2 ❑ --- v* 0 O o d) 0_ - 0 O ❑ U N o -JLt � C 03 c6W 0 � 0 0 Lu CC 11) W ca LU❑ ' 0 * a) o U) 0 a 0 � x .515 L W J� z a a) z (0co oCC tiQ °) = LLz = z 0Y ca pW OI- a) C Q a) I- � a LT c 0 oQ � 00 > 0. — O 0� ❑ W L J _2 _ W 2 - W 0 ©❑ m0 ❑ U c ID p _ 2 N -E _O < c _Z ❑ CLu C � a Oc c r U) ,- Oz � Q � 0 o - 2 H � c 3 ami C; O � — J ❑ � J O p � -� rn � OQ 0 � � 0 QM E � c J , D U) co c0 ❑ moo ❑ c) Z W (� CO e p -co CO N ❑ ❑ oo < r Z a O O m 0 L V O 6 Z d a) ' d N- N- J N * p Q a� dX Q2 � d E ay 2 � W O NinpcociMmco : aico a) Z * w on * ❑ �)W , * D Ocn DU) II r- Ct = x xN xiO .` , c Q i0 J � � WNF- � * d Et X F- I I > @r Y O U G1 < Z W * r 0 � ~ J * O W O � I? 2 Z > U) — N cM ct N I C U p re 4' co < _ ctr, oL0 c � U) � 6- in a \ a E * W � O2 N J < a) ,- eco a) m a) O * U � 3 3 3 ID ID m >' � � dm Ea) � � x EL❑irnLo � � x � � ❑ ~ � Q � W JO222z � � � Q Oa 1-° 2 o � Ob ww � � 2b --CN -I z � - MUW W c� c� cncn ❑ Q '' a,cfl f- O CC >� c O U) O .- II Et � W > ❑ Ch in I'- W Q •a II U- O CI n- 5 O LL > O U O z 5 .- --7-. O > < > > W coOco O CO D N 3 N 12 co L U O �C) W C U) a ~ CCU) W O in � c) Z > CCO Z N- (N N Z 6 II co X to U) U) Z co m U) U) z Y (Ni I~i N O U) W - i= I- 10 O -a o F- 01 DNzJ > w < '- W OctU _ cnaF- z000Ozrn m c � ^Q X � » � o ❑ dim --.JO �t II F/3 U) ❑ F- F- F- HOo � -0 O i_ cZ . O = b p Z 2N a) N O ~ ~ N E ❑ O 1-15 J ` > J ❑ J U O ❑ ❑ (� ❑ U `DT) o U N OUO Utz o00D o � z00 ❑ ju LLJ 0) W0z * Ca 0I— I— HIl �* LLI UJ co 111 Et � � p c * o2 � a) * * �2 � * * 2 Ea- o H- Qcci) : FQ- CC * ? oom0 � En• o to to .- v- co O co O O O CD c- C) O CD O N N N N N N N co co N- co NO N N '- N N • • 0) = o I- n (7) co ° o N > Q a0 co N ~ c 0 co WD X -a c ° c /tel 0- (7) Nc0 W sa _ cL J () X b a .0 N Y N c 0o a O N ° d g W w Q aU Q" Qei0H o E0 a) WU aCl) d JQY gQYT. oc Q J X U d = 0 co U I a) O E Q aa)i 0 b QU Q M a F> _' E .,: J a - m c ~ N > + Q F O a > a LU CD cin (nQQ N = W Q C N w Q co _• N 0 • c d 2 J 0 - ° z • a� N U Q U) O W M = J * - 00w et U U L W r (n LU a W p U '� G1 X © O W 12 Q' Cfl •. - M Q C7)'c m O O co co O. N () w J r0 0 X O 0 (n N i_ N II LO Q a) O - n as .4- < pW W Q H F�- c C7)- ,',---1- Q < Q .cCO O j O 9--- o Z a N < * Q X o U o 0 Y * 3 * -A 1- =1 a }. - 0 2 * CO Co < w � � 0 V— Ztog � S um O § H W 2N- W -,9 NF- Z0 ' Op 0 JU c N O Q .- 1_ p < ) 0 LU a I � N \ N Q ~ d * a) I Q p Q O < (n W W O p Z N co W J * a (n a 0 IL Z (n D * z a) (n * Q r ( J W ¢ J J < a Y � W ? a _ NUa - (n U) �p0 NQ * a) 2 (n X O Q W -0 0 a) a to O �w � cnp• ja > W F- wYaNcN -- zv - > - O • _ - C1+- �+ fa Q � II E � EWY u) '1UQFOz � r a' (noWcO N 7 > X' N •� oZ � � � > CCaCCaQ U � aC� O ami t� � �n � r a) ._ � WQ 0 W Xa , QrnQQa U asz0 C2 00- N N a) a. a(9Z c� 1- i_ -1amNwr -z - wn ,oUQoQW o Dia Dw73OZ c z Zoa � �> > " DwWp °' � maF= �' Z� U �0 II a ° c�a °co � II F- aWQ OHOo � 2W � 0W �W h- Z0 � > 0 Oy og (S j = UZ c U o Z Et III - � JUDH QO° _ W ¢ OV 'n (n * coca U OUm cn Q. U) z w X m II >W Q > m > Y , O > m m p II (n * m m J m H d- J a Z fx0Qin > _- (nm > C' J ,- � O (� 0O cx0QQO o cr a) WWDO * OU * -- amu * Zwc, a v0 � 0c ce , • ou) * � Z ? * o rn 3 c) � U O Q J * H o > * J LL * * -8 O O E * a' * CO CO CO CO CO CO CO O O r r r O O O p N N O N NI- N N N N N N N N Lo Co Co O N N N N N M r r r r r . • • H LL Lu 0 Z w � II z 0� — o o Fci -Q �. .� z 0 W *k M o Z Z O J F- N Z E M Z oo Z n• to ¢ Cas H J M O aU O � a) U CV- CD a 0 • U J 0 v) 0O F- - N U o D I 0 i0 Q a � N o � c ) F- 20 w CD 1- a- 0 F- � 2 -(7) w M o � ccoo = :o a co c\I CV 45 J ~ Q W Q N W 0 'cr �- N L.L. co = f: (0 Q I W - N Q 2 �n I Z N m .€ -j Z Q < F- ¢ _M 4 en 0 C � M z < Z Q •3 -I *ktS, �* f- _o _ _ z Z co co ) 0 J -3 o 0 0 � 0 Z LZF- - Z 0 0 U d 0 0 ,.,_ •Z ov W O c0 OD �, N m Y D �(n (0 F- O �N_ W 2 - J - J J c 0 U C[ CL O Q � NF- U WO la O cF- O 0 U ,3UJUr0 0) Q F- OW d d I"- c) H O ~ 0 is w 0 C� Oa � D IT ITco O _ op 2 ao F- U 00 JD c c0 � 0cC > H 0LUF- ww a Uro a 4- Z Q¢ En * Z2 Q �7 H o2 0 w a u) - 2 Z o 0 0 � U a� OH Co () 0 0 N o - J N W' D �•+ Q * (� M Z ¢ CO L 0 0 J W 0 * 0- 0- 2 2 Q..2 0 j 0 ‘- u) J 2 Z : (n Q � 2Z * 22 -_ * >>� N = ©Z ct o 0 0 (� to Y M Z zo 0S bo QD O O N * CSO > N cr < 0 0 -0 d 1- z J F- ©* O � i2 CD v co CD * oM � 00N * CO _ W � * WUF- W O N W W' J �- * N D N O : N CO N * O N > C * = F- D 1- * J Ce O U U W ~ CO y W' V N N N co N r 43 C_O F- a J CO chs - Y0 Ua0 `- 3F- J 0 N � ON � � QF- ONF- W EO W O Ur (o 4) U I� O F- W N Q J F- Q N Q Q Q N N Q J p N (n Q z C n: 010, 8 O2 = 7 ,F, U ~ H aaOcoao � � ' � U -Ca � � 2EON CrU = aOIUZZC 1- F- O z F- Z � F- F- F- F- Z � F-CNIZ � Z W ~ Wo�oQzcn U- 0H0H < OU- ZZF- 0 w zOOzzzzOWZ W - - 00w =coHOF- 0 � W w S ZZ O J Q w w W O O m < W O W W O O O O W W O > CD W 0 0 0 y`1. Q• ) 2 0- 0 Cl- D Z J J J (n -6 D D -6 -6 -6 -6 D D 0 M D F- Z J• Q m -- ~ Z Q > Z - J J - - - J Z Z J J J J Z Z J J �� z U� F- F- Q F— 0_ D Z O Z F- U U �-.b 0 O J F- J J J J i J a F-- cL d N Z 12 -4- 2! W F- W2WUJZO00, c�iacYiO D c2 UZZUUUUZZUW � zU1 W Wzrn 0 wLtw O 0 -1 (300 ° C3 (3 ° 00 ° ° =70 w � YCOF- OZZ - aF- JzZOOF- F- Z o zOF- O0E- F- F- F- UGHHOO (nF- F- O O (n * < D , H0Q -- U * W W < < IQO W * * W W W W * * w W N— * F- W QD * * - < IQ-' — * * (nwrx wccco0' F- U) * * (nC) U) U) * * U) U) c6 : * Q (n30 * J co (0 co _co ON O O O C) 0 O O N N N N N C7 x- N CO LO LO N N N NN i 0 N co a) D D a) D O Q L z E u) W co a) o z m O w * w Y D O U) U) N m Q I- Q -CD o WU Q : Ea Q O J .( .,7 o O -J Q o_ II • Ill (D CO O co. Z N p — 0 --- 0 Q •0 - O - 'Q ...-• a) co +:r Z IL i Y E L. 2 Q il - i U) (I)O "C N. LO >N O ( 6 _5 d . I- i ( m - o E UQ a_ 4- Z QA Q o- > �W F- i .g. — COU O « JI— CO Lo C 0d 0) ZUOQr c) -0 o -• j w Q Z w III E) N J co �' NQdO � E (:) .(7) - u) ca 20- < DZ a) < Q-- Q OOZ OH 0) v) v. • wC ' — co — D X o _ cc 0 3 rn jj N m o > O I__ 7 W O' Q CO ........ C H IX O N J p L C Cr) m L z W W J 0) E D II II o Z' O a I- W II 0) .L J Q u7 ,— to I co L -(13 p Aro JOW *K 1- _0 ,- I- U- aOZ 0) (0 p p W p N N _0 C") CO co La co co m N N N TRS= 4"CMV SAFETY NOTE: WELL REQUIRES A SSSV.—9-5/8" _ IVVELI.-FAD FMC N K_0 7 A CSG SET ON EMERGENCY SLIPS. OLD PEWS& ACTUATOR= BAKER LOWER 1452'OF PRE-SDTRK TBG/PKR/TP P&A'D OKE.EI EV= 58.6' W/CMT. WELL EXCEEDS 70°(d1 12958'"" REF.ELEV= 52.65' , BF.ELEV= 19.7 KOP= 950' IMax Angle= 79 @ 14364' 2046' H4-1/2"TES SERIES 10 TRSSSV, =3.813" D DatumMD= 18042' Datum 7VD= 9200'SS H X GAS LFT MANDRELS 13-3/8"CSG,68#,L-80 BTRS,D=12.415" 5153' V ST MD TVD DFS/ TYPE VLV LATCH PORT DATE 3 3625 3060 62 CA DMY 12 0 08/11/10 1 13-3/8"CSG,72# L-80 BTRS,D=12.347" I—{ 5849' X, 2 8684 5432 62 CA DMY 12 0 08/11/10 gig ii1 12527 7231 62 CA `DMY 12 0 08/11/10 13-3/8"CSG,68#,L-80 BTRS,D=12.415" — 5930' 'STA#1=COVERED BY STRADDLE PKR 4-1/7 NS EXT STRADDLE PKR w/PISA H 12088'-12616' 12572' H9-5/8"X 7"BKR ZXP FKR/HGR,D=6.3001 &2-7/8"X NP @ 12093',D=2.313"- 527'NS QCLL PATCH w/RJ,ID=2.800" 12597' —4-112"HES X NP,D=3.813" COVERED BY STRADDLE PKR STUNG INTO 45KB PACKER @ 12616' oz.? ►ei (02/05/16) — t�� IF_ 12618' —17"X 4-1/2"BKR S-3 PKR,ID=3.867" Minimum ID =2.313" @ 12093' I 12626' H2-7/8"X LOCK,D=2.313" 2-7/8" X NIPPLE I 1 12641' 1—f4-1/2"tS X NP,D=3.813' 1 I 12662' 1—4-1/2"HES XN NP,D=3.725" 1 4-1/2"TBG,12.6#,L-80 NSCT, H 12673' I .0152 bpf,ID=3.958" \ 12675' H4-1/2" LEG, =3.95 \\r // 1 WD 88" \ 12675' H E.MD TC LOGGED 04/21/03 12678' —7"F1Y DFL 511 X 4-112"WORK_ 521 XO,ID=3.938" MILLOUT WINDOW (NK-074)12731'-12747' —TOCK — 12731' 17595' HI4-1/2"MARKER JT(20') 19-5/8"GBP1—.. 12765' I 18173' --I TOP OF FLL 444411111 4 � 9-5/8"CSG,47#,NT-80, 0732. bpf,ID=8.681" -- 14965' r-11......- 41.........4 11111/1/111/11.1 - 411/111/1111/11 .11/1/1111Ilt1 FORATFON SUMMARY *1111111111111 REF LOG:SWS GR/CCL ON 04/26/01 •/.004.1. _ ;As*We; ANGLE AT TOP FRF:58 @ 17710' .;.,� Note:Refer to Production DB for historical perf data PBTD —1 18384" �� SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-3/4" 6 17710-17830 0 04/26/01 4-1/7 LNR, 12.6#,L-80 HY D 521,.0152 bpf,D=3.918" H 18512' 2-314" 6 17940-18085 0 04/26/01 DATE REV BY COMMENTS DATE REV BY COMVENTS NIAKUK UNIT 06/28/94 ORIGINAL COMPLETION 02/25/16 DLW/JMD SET LWR PATCH PKR(01/26/16) WEL: NK-07A 04/29/01 CWKAK FIG SIDETRACK(PK-07A) 02/25/16 NXW/JMD SET STRDL PKR ASSY(02/05/16)_ PERMf No:`2010630 10/28/10 JWF/PJC SET RBP(10/05/10) 03/01/16 GC/JMD ADDED REF.ELFV AFI No: 50-029-22410-01 02/18/11 MB/JWD ADDED SSSV SAFETY NOTE SEC 36,T12N,R15E, 1250'NSL&1099'VVEL 03/26/14 GJF/PJC TRSSSV UPDATE — — ' — 12/08/15 NLW/JMD FULLED RBP(11/07/15) BP Exploration(Alaska) I Imag -~rojectWell History File Cover( ,ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. '~0 L- _O-OB Well History File Identifier RESCAN DIGITAL DATA [3 Color items: / Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERYL~'~INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL.~~WINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds L_~/~ E] Other DATE /SI Scanning Preparation I x 30 = ~Z(~_ + BY: BEVERLY ROBIN VINCENT SHERYL~INDY TOTAL PAGES Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~__ YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: __ YES NO RESCANNEDB?': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: IS~ Quality Checked 12/10/02Rev3NOTScanned.wpd • • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 4 " *A*415) IL: 8 201', July 6, 2011 1 Mr, Tom Maunder Alaska Oil and Gas Conservation Commission act o 0 ( 7 333W ue Anchorage, Alaska 99501 \<"*" Subject: Corrosion Inhibitor Treatments of GPMA Niakuk Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA Niakuk that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Mehreen Vazir, at 659-5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Niakuk Date: 05/15/11 * Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion Inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal NK -01A 1760280 500292015601 P&A 3/9/91 NA NA NA NA NA NK -02A 1780790 500292018001 P&A 3/13/91 NA NA NA NA NA NK -03 1780940 500292035000 P&A 4/14/80 NA NA NA NA NA NK-04 1842000 500292121700 P&A 4/14/98 NA NA NA NA NA NK-05 1850270 500292129000 P&A 4/15/96 NA NA NA NA NA NK-06 1852760 500292148600 P&A 4/15/96 NA NA NA NA NA NK -07A 2010830 500292241001 0.2 NA 0.2 NA 0.9 4/30/2011 NK-08A 2010290 500292249101 0.2 NA 0.2 NA 0.9 4/30/2011 NK-09 1941400 500292251800 2.1 NA 2.1 NA 17.0 4/30/2011 NK -10 1931840 500292242600 1.5 NA 1.5 NA 11.9 4/30/2011 NK -11A 2020020 600292278901 1.5 NA 1.5 NA 11.9 4/30/2011 NK -12C 2030550 500292241403 1.8 NA 1.8 NA 31.0 4/30/2011 NK -13 1981340 500292289300 2.3 NA 2.3 NA 22.1 5/4/2011 NK -14A 2060310 500292288801 1.8 NA 1.8 NA 17.0 5/4/2011 NK -15 1970320 500292274500 1.8 NA 1.8 NA 18.7 5/4/2011 NK -18 1940220 500292244700 2.5 NA 2.5 NA 20.4 6/4/2011 NK -17 1981650 500292270900 3 NA 3 NA 20.4 5/4/2011 NK -18 1931770 500292242100 2 NA 2 NA 17.0 5/8/2011 NK -19A 2010700 500292250701 1.8 NA 1.8 NA 15.3 5/6/2011 NK -20A 2050400 500292242901 2.1 NA 2.1 NA 13.6 5/9/2011 NK -21 1940880 500292248700 2 NA 2 NA 22.1 5/15/2011 NK -22A 2012280 600292240201 1.5 NA 1.5 NA 11.9 5/11/2011 NK -23 1940350 500292245500 3.6 NA 3.6 NA 20.4 5/10/2011 NK -25 1970680 - - 500292276000 2.5 NA 2.5 NA 15.3 6/11/2011 NK -28 1940050 500292244000 2.9 NA 2.9 NA 17.0 5/11/2011 NK -27 1950210 500292254700 2.3 NA 2.3 NA 13.6 4/30/2011 NK -28 1960930 600292267800 Sealed Conductor NA Sealed Conductor NA NA NA NK -29 1961900 500292272400 1.7 NA 1.7 NA 10.2 4/30/2011 NK-38A 2042410 500292254001 3.1 NA 3.1 NA 13.6 6/8/2011 NK-41A 1971580 500292277801 9.1 NA 9.1 NA 54.0 5/9/2011 NK-42 1941080 500292249900 2 NA 2 NA 13.6 5/9/2011 NK-43 2010010 500292299800 1 NA 1 NA 5.1 6/9/2011 NK-81A 2080350 500292289301 14 NA 14 NA 110.5 5/15/2011 NK -62A 2030470 500292285201 1.3 NA 1.3 NA 13.6 5/4/2011 NK-65A 2050830 500292288901_ 1 NA - 1 NA 8.5 5/6/2011 Well Job# Log Description Date BL olor CD P2-37A 11491392 MEM PROD PROFILE 11/15/06 1 Y-23B 11418299 MEM PROD PROFILE 09/06/06 1 NK-07A 11588698 MEM GLS 12/21/06 1 07-01A 11555031 GAS ENTRY SURVEY 12/19/06 1 NK-08A 11485780 MEM GLS 12/20/06 1 NK-27 11588699 MEM GLS 12/22/06 1 NK-43 11513659 PRODUCTION PROFILE 12/22/06 1 DS 09-32 11555530 INJECTION PROFILE 12/16/06 1 P2-14 11539745 MEM PROD PROFILE 12/07/06 1 Y-05A 11539744 MEM INJECTION PROFILE 12/06/06 1 s-02A 11285936 MEM PROD PROFILE 08/17/06 1 12-32 11536184 USIT 12/05/06 1 MPS-10A 11486087 COMPOSITE WFL/LDL 12/14/06 1 Z-19A 11226013 SCMT 10/28/06 1 Y-30L 1 11588700 MEM PROD PROFILE 12/23/06 1 E-11 B 11434757 DSI 10/24/06 1 E-11 B 11434760 DSI 1 0/29/06 1 E-11B 11434760 FMI 10/29/06 1 G-14A 11485777 MEM PROD PROFILE 11/27/06 1 G-14A 11485777 SCMT 11/27/06 1 0\ Schlumbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ '~) Qó (-O~-) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE .COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~A""l:n JAN 3 0 2007 900 E. Benson Blvd. ~ Anchorage, Alaska 99508 Date Delivered: 01/25/2007 NO. 4125 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay c . . Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: e e '" MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_ Inserts\Microfilm _ Marlœr.doc STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION 0 REPORT OF SUNDRY WELL OPERATIONS OCT 52004 Alaska Oil & Gas GOIli:. LiJITH¡IISSIC Stimulate 00 OtherO Anchorage WaiverD Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 201-0630 6. API Number 50-029-22410-01-00 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Noperator BP Exploration (Alaska), Inc. ame: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 52.65 8. Property Designation: ADL-0034629 11. Present Well Condition Summary: Total Depth Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New PoolD Operation Shutdown 0 Perforate 0 4. Current Well Class: Development Œ] ExploratoryD Service D Stratigraphic 0 9. Well Name and Number: NK-07 A 10. Field/Pool(s): Niakuk Field 1 Niakuk Oil Pool measured 18512 feet None Effective Depth true vertical 9588.5 feet None measured 18384 feet Plugs (measured) Junk (measured) true vertical 9489.9 feet Casing Conductor Liner Liner Production Surface Surface Surface Length 80 107 5833 12700 5120 696 81 Perforation decth: Size 20" 94# H-40 7" 29# L-80 4-1/2" 12.6# L-80 9-5/8" 47# NT-80 13-3/8" 68# L-80 13-3/8" 72# L-80 13-3/8" 68# L-80 MD TVD Burst Collapse 34 - 114 34.0 - 114.0 1530 520 12571 - 12678 7252.5 - 7305.9 8160 7020 12678 - 18511 7305.9 - 9587.7 8430 7500 31 - 12731 31.0 - 7333.0 6870 4760 33 - 5153 33.0 - 3777.1 4930 2270 5153 - 5849 3777.1 - 4100.5 4930 2670 5849 - 5930 4100.5 - 4136.9 4930 2270 Measured depth: 17710 -17830,17940 -18085 True vertical depth: 9060.5 - 9125.99, 9189.8 - 9280.54 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 29 12672 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" HES TRSSSV 7" Baker ZXP Liner Top Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): 17710 -17830 Treatment descriptions including volumes used and final pressure: 87 Bbls 7.5% DAD w/10% Xylene Acid @ 3660 psig Representative Dailv Averaae Production or Injection Data Gas-Met Water-Bbl Casing Pressure 0 2543 2500 0.3 3081 800 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron J1~("~~ For~è<J\~~frbmOt 9 2004 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - Daily Report of Well Operations - ! Signature @ 12615 @ 2043 @ 12571 Oil-Bbl 509 775 Tubing Pressure 597 782 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ] ServiceD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: NIA Title Production Technical Assistant r1 Phone 564-4657 I I A L OCT Q¡ tl Date 9/29/04 RBDMS BFL NK-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/04/04 **** WELL FLOWING ON ARRIVAL ****. DRIFT W/ 3.5 CENT. & SAMPLE BAILER AS DEEP AS POSSIBLE.. ANGLED OUT @ 18,021' SLM. SAMP BLR EMPTY.. **** LEFT WELL SI FOR CTU **** 07/05/04 CTU#5: FILL CLEAN OUT/ACID. «<CONTINUED FROM WSR 7/4/04»> WELL SI UPON ARRIVAL. BRING WELL ON LINE FLOWING W/ AL. RIH 2.5" JSN. JETTED FILL W/ FLO- PRO FROM 18,1001 TO 18,158' CTD, RETURNS TO TANK. TAGGED HARD BOTTOM AT 18,158. CHASED FILL TO BOTTOM GLV @ 80%. JET 50 BBLS DIESEUXYLENE FROM 17,6001 TO 18,158' CTD. OPEN WELL TO SYSTEM TO DROP WHP. CONTINUE JETTING THROUGH FILL TO 181731. DISCUSS DEPTH W/ TOWN, DECIDE TO POOH. CHASE OOH AT 80%. MU BHA #2 (33/8" RETRIEVABLE PACKER). RIH TO 17,880'. HAD PROBLEMS GETTING PAST GLM #1. WORK THROUGH, CONTINUE RIH AND SET IBP @ 17880 CTD. INJECTIVITY DOWN COIL IS 3630 PSI @ 1 BPM W/ IBP SET (NO INCREASE IN WHP WHILE PUMPING DOWN COIL, GOOD INDICATION THAT IBP IS HOLDING). BEGIN PUMPING 100 BBLS OF 7.5/10 DAD ACID (TITRATION = 7.4% HCL AND <50 PPM IRON). «<CONTINUED ON WSR 7/6/04»> 07/06/04 CTU#5: ACID STIM W/ ISOLATION PACKER. «<CONTINUED FROM WSR 7/5/05»>. CONTINUE PUMPING 100 BBLS OF 7.5/10 DAD ACIDIXYLENE. FLUSH W/ 50 BBLS 1% KCL BEHIND PIPE. FINAL INJECTIVITY = 3435 PSI @ 1 BPM (COMPARED TO 3630 PSI @ 1 BPM BEFORE PUMPING ACID). <NOTE: PUMPED FILTERED 1 % KCL DOWN BACKSIDE AT MIN RATE DURING ENTIRE ACID JOB. BACKSIDE PRESSURE SLOWLY INCREASED, MUCH AS IT DID DURING THE INITIAL BACKSIDE INJECTIVITY TEST. THE IBP DID NOT APPEAR TO BE LEAKING DURING THE STIMULATION.> RELEASE IBP AND POOH. IBP WAS MISSING ONE 1" STIFFENING RING. PAD OPERATOR TO POP WELL UPON DEPARTURE. «JOB COMPLETE»> FLUIDS PUMPED BBLS 647 947 50 20 100 1764 1 % KCL XS 1 % KCL 50/50 Diesel/Xylene Flo Pro 7.50/0 DAD Acid w/1 0%, Xylene TOTAL Page 1 SCANNED OCT 0 9 2004 TREE = 4" CW W8..U-EAD = FM:; no. ....m....~.." .. .. ACfUATOR = BAKER KB.. a.EV = 5 Z-. I.? 5'" ...Qe:1" BF. ELEV =-------19.2" !<OF);; ~--------"'---- -"---~-95õ' Max Angle = 79 @ 14364' DabJmMD = - 1727"3" Datum TV D= 8800' SS 113-3.18" CSG, 72#, L-80 BTRS, ID = 12.347" H 5937' r-JI Minimum ID = 3.725" @ 12662' 4-1/2" HES XN NIPPLE 19-5/8" X 7" BKR ZXP PKR/H3R, ID = 6.300" H 12572' I IT' HYDRlL 511 X 4-1/2" HYDRlL H 12678' I 521 XO, ID = 3.938" I - PERFORATION SUMMARY REF LOG: SWS GR/CCL ON 04/26/01 ANGLEATTOPÆRF: 58 @ 17710' Note: Refer to Production DB for historcal-)erf data SIZ E SPF INTffiV AL Opn/Sqz DATE 2-3/4" 6 17710- 17830 0 04/26/01 2-3/4" 6 17940 - 18085 0 04/26/01 1 WHPSTOO< H 12731' I I 9-5/8" aBP H 12765' I I TOPOFOLD CUT-OFF 4-1/2" TBG H 13364' I I TOP OF 7" LNR H 14791' I I 9-5/8" CSG, 47#, NT-80, .0732 bpf, ID = 8.681" H 14965' ~ I 7" LNR, 29#, L-80 BTRS, .0371 bpf, ID = 6.184" H 15694' I N K-07 A 8 L I :g I :K J A A Y X X y :1 ..I. y ~ --; ~ .. .. :.a DATE REV BY DATE REV BY COMrvENTS 06/28/94 ORIGINAL COMPLETION 04/29/01 CIi'KAK RIG SIDETRACK (N<-07A) 07/06/04 BJrvtL/KAK FLL Q.EANOUT SCANNED OCT 0 9 2004 SAFElY NOTES: 9-5/8" CSG SET ON eJI ERGENCY SUPS. OLD PERFS & LOWER 1452' OF PR&SDTRKTBG'PKRlTP P&A'D W/CMT. WELL EXCEEÐS 70° @ 12958' 2046' H 4-1/2" HES TRSSSV, ID= 3.813" I ~ GA S LIFT tv\A. N £:RB...S TVD rEV lYPE VLV LATCH PORT DATE 3004 62 CA OOrvE 12 05102101 5375 62 CA OOrvE 12 05102101 7174 63 CA SO 12 05102101 ST MD 3 3625 2 8684 1 12527 I 12597' H4-1/2" I-ES X NIP, D = 3.813" I I 12618' H 9-5/8" X 4-1/2" BAKER S-3 A<R, ID = 3.867" I I 12641' H 4-1/2" HES X NIP, ID= 3.813" I I 12662' H 4-1/2" HES XN NIP, ID = 3.725" I I 12673' H4-1/2" TBG, 12.6#, L-80 NSCT, I 1.0152 bpf, D =3.958" 12675' H 4-1/2" WLEG I H 8..MD TT NOT LOGGED I 'MLLOUTWINDOW 12731'- 12747' 17595' H 4-1/2" MARKERJT(20) I TOP OF RLL 1 H A3TD I 14-1/2" LNR, 12.6#, L-80 H 18512' I HYD521, .0152bpf, ID=3.918" I ~ OOMMENTS NIA KUK UNrr WB...L: NK-07A ÆRMT No: 2010630 API No: 50-029-22410-01 SEC 36, T12N, R15E, 1250' NSL & 1099' WEL 8P Exploration (Alask a) ? 0 f'lk) .( 0 ~ ') DATA SUBMITTAL COMPLIANCE REPORT 4/18/2003 Permit to Drill 2010630 Well Name/No. PRUDHOE BAY UN NIA NK-07 A /~ Completion Statu 1-01L Current Status 1-01L UIC N MD 18512"/ TVD 9589'- Completion Oat 4/29/2001 REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Media 11.- C I~ I~~ i L "f-./ Iv/ i iV I I kŸ ~ Digital Fmt De Density Ind Induction/Resistivity Ne Neutron ~ R v V'" ~-- C Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? '- Y / N ~ Analysis Rp.C':p.ivp.rf? Comments: Y/N ----- Mud Log No Name [Qirectional Survey Dlféctional Survey 10225 10282 Interval Start Stop Sample No Log Log Run Scale Media No 3 3 3 FINAL FINAL FINAL FINAL Operator BP EXPLORATION (ALASKA) INC Sfctl )~ fJ.p ~bUI API No. 50-029-22410-01-00 Directional Survey ~L~ -- (data taken from Logs Portion of Master Well Data Maint) .-, Interval OH/ Dataset Start Stop CH Received Number Comments ----.-- - - 12492 18510 Open 12/1/2001 !Jf'0572 v' 12492 18510 Open 12/1/2001 10572 12492 18510 Open 12/1/2001 v.¡ 0572 12590 13000 Case 8/3/2001 ~ 0225 12590-13000 12590 13000 Case 9/12/2001 ..(0282 12590-13000 ch 5/14/2001 Directional Survey Paper Copy ch 5/14/2001 Directional Survey Digital Data 12590 13000 CH 8/3/2001 -t0225 12590-13000 Digital Data 12590 13000 CH 9/14/2001 J0282 12590-13000 digital data --, Sent Dataset Number Comments Received Daily History Received? (y)N (Ÿ)/N Formation Tops Permit to Drill 2010630 DATA SUBMITTAL COMPLIANCE REPORT 4118~2003 Well Name/No. PRUDHOE BAY UN NIA NK-07A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22410-01-00 MD 18512 TVD 9589 Compliance Reviewed By: Completion Dat 4/29/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N Date: Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2781 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott, Niakuk 05/13/03 Well Job # Log Description Date Blueline Color Prints CD NK-14 ~ (::{ i,~' O(~ SBH.P SURVEY 04/20/03 1 NK-08A ~..C.t .O?..c~ SBHp SURVEY 04/19/03 1 NK-20 I[ c~.~ i ~ i SBHP SURVEY 04/20/03 1 NK-21 [c~ ,~;~3~'~ SBHP'SURVEY 04/19/03 1 NK-07A ~ [, {~ '.~ SBHP SURVEY 04/21/03 1 4-18/S-30 i~..~ · i ~ ~ PSP GLS 04118/03 1 1-33B/L-24 .'tq~- ~,.~ LDL 04/19/03 1 3-45/M-29 i {~'~ - O,~ i INJECTION PROFILE 03127/03 D.S. 15-47 tCl~ ~t'~ ~ LDL 03/21/03 1 D.S. 17-11 I ~' - oq,~.~.t-~ GLS 04/27/03 1 D.S. 18-14A i~. 00'1 LDL 04~03~03 1 D.S. 13-29L1 '~O'~- ' C~C~ PRODUCTION PROFILE 04/06/03 1 D.S. lS-03A [.~L.~ -- [~'~- LDL 03~27~03 1 D-05 't"tO, I~ {,, iPRODUCTION PROFILE 04/13/03 1 D.S. 9-20 ~"[~. C ~. [ :INJECTION PROFILE 04/15/03 1 E-13A j cl"~..,.(~ (~ "Z.- SBHP SURVEY 04~24~03 1 D.S. 1-28 i~(~ ' O~ .~ CHFR 03131/03 1 D.S. 4-18 i ~.r~; ~ ~.~-.~ FLOWING BHP & TEMP 04/13/03 1 J-23 I ~ -~ O '~ ~ LDL 04125/03 1 N-20A tqC~ - I ~ ~- CHFR 04/10/03 1 D.S. 1-34 I ~(4:' --I 1 ~-~ CHFR 03~29~03 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH T,O: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'FI'N: Beth Received by: ~ 12/06/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1672 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Niakuk Color Well Job # Log Description Date Blueline Sepia Prints CD NK-07A ~C)t-~)~o '~ 21342 CDPJADN 04/22/01 1 NK-07A 21342 MD VISION RESISTIVITY 04/22/01 1 1 NK-07A 21342 TVD VISION RESISTIVITY 04/22/01 1 1 NK-07A 21342 MD VISION DEN/NEUTRON 04/22/01 I 1 NK-07A 21342 TVD VISION DEN/NEUTRON 04/22/01 1 1 S-17B (-~C~/--IL~.~ 21483 SLIMPULSE/GR 08/16/01 1 S-17B 21483 SLIMPULSE/GR 08/16/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED 2001 Date Delivered: Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-571 ATrN: Sherrie Received 11/14/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-$711 ATrN: Sherrie NO. 1631 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay,Niakuk Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 4-40 j G~ )--'-'1 ~ PSP LEAK DETECTION LOG 11/06/01 1 1 D.S. 5-02 } -~ q-~),"~ PSP LEAK DETECTION LOG 11/03/01 ] 1 D.$. $-05B j ~/p-/~ PSP LEAK DETECTION LOG '1'1/04/01 1 1 D.S. 18-28 I ~ ~ "O~,,J' PSP LEAK DETECTION LOG 11105101 1 1 FI-0?A _,,,~-'OJ O ~ TEMPERATURE $UFIVEY LOG 1'1/05/0'1 1 1 NK-07A c~.~C)I'-OIm.~ PFIODUCTION PFIOFILE-GL$ 10/31/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99,508 Date Delivered: RECEIVED NOV 1 2001 Alaska 0il & Gas Cons. Commission Anc~3mge Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Sherrie Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AITN: Sherrie 11/12/01 NO. 1614 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 9-42A I C~,.-OO-'~ PRESS/TEMP SURVEY 10/22/01 ],,. 1 R-16 I~i-~ "'7 ~ PROD PROFILE/DEFT 10/23/01 .1, 1 NK-07A c'~ OI-"' ~)~'~.~ PROD PROFILE/DEFT 10/17/01 ,1- 1 NK-10 /O '~.,, / ~ ] INJECTION PROFILE 10/28/01 ,],' 1 NK-10 t ~ ~,' ' o ~ TEMPERATURE PROFILE 11/01/01 ,t- 1 F-31 ['~-/~'"7 21414 RST-SIGMA 09/13/01 1.,' 1 1 C-37A C~C)I-/(J~ 21434 MCNL 09/]5/01 '1' 1 1 G-30A ]~ --t~"7 (p 21191 RST-SIGMA _ 04/09/01 ,,1 1 1 D.S. 1-10 I "-7.~.-'~;~ 21192 RST-SIGMA 04/05/01 ,3- 1 1 D.S. 4-30 J~5---O~'~ 21193 RST-SIGMA 04/06/01 ,1' 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Bivd. Anchorage. Alaska 99508 Date Delivered: RECEIVED NOv t 3 2001 A~mka 0il & .Ancbor~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 Al-tN: Sherrie Received ~ ~ 09/12/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1435 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD IK-07C /~_/O<7 20034 MCNL 12/10/99 1 1 1 !S-20A ~,~ L0/-f-~.~-~ 21348 MCNL 0711810t '1 X-16Lt (REDO)~o~O~ 21330 MCNL 06111/01 D.S. 15~2A (REDO~-~ 20307 MCNL 07116100 1 .NK-07A (REDO~(%/~~ 21341 MGR 04126101 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO.' BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: RECEIVED SEP 1 4 2001 A/aka Oil & Gas Cons. Corn, m~ior~ Schlumberger GeoQuest 3940 Arctic Bivd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Schlmberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 1335 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Endicott, Niakuk,Milne Point Well Job # Log Description Date BL Sepia Color CD NK-07A '~-OI--O~ 21341 MGR (PDC) 04/26/01 5-021SAG 10 /I~/-//II~ PSP-LDL 07/23/01 · MPC-24 ;~'~{ '- O'~fl/ MDT 07/25/01 7/31/2001 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: RECEIVED BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Schlumberger GeoQuest AUG 0 5 2001 3940 Arctic Blvd Anchorage, AK 99503 ~i~l~ 0~1 & (~aS C0fl$. ~ ATTN: Sherrie ~~ Re~ived STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION COMMi;:,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL[=~ GAS D SUSPENDED E~] ABANDONED r~ SERVICE I~' 2. Name of Operator ~-,-~~ I I 7. Permit Number BP Exploration (Alaska), Inc. 201-063 P. O. Box 196612 Anchorage, AK 99519-6612 50-029-22410-01 4. Location of well at sudace i U~':.i~:'.-T":~';-".',:i:,:-~ 9. Unit or Lease Name Niakuk 4029' FNL, 1124' FEL, Sec. 36, T12N, R15E, UM (asp's 721440, 5979782) ~ :.....,.~;~ i' 10. Well Number At Top Producing Interval. ~/, Z,~ %~...~./~ 2022' FNL, 2146' FEL, SEC 27, T12N, R15E, UM (asp's 709647, 5986732)i '~,"~:;Fii'!;? i NK-07A At Total Depth i ._~'~'_~ , 11. Field and Pool 2011' FNL, 2735' FEL, SEC 27, T12N, R15E, UM (asp's 709059, 5986727) ~' ............. 5. Elevation in leet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 52.56 feetI ADL 34629 Niakuk Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions April 13, 2001 April 20, 2001 April 29, 2001I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 18512' MD /9589' TVD 18384' MD /9490' TVD YES F~ No [~I 2046' feet MD 1 900' (approx) 22. Type Electric or Other Logs Run MWD GR/Res/Neu/Den/PWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 94# H-40 Surface 80' 30" 260 Sx Arcticset 13-3/8" 72#/68# L-80 40' 5937' 16" 1943 Sx PFE & 375 Sx Class G 9-5/8" 47# NT-80 38' 12731' 12-1/4" 380 Sx Class G 7"/4-1/2" 29#/12.6# L-80 12572' 18512' 8-1/2" 794 Sx 15.8 ppg Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-$/4" guns & 6 SPF 4-1/2" 12.6" L-80 NSTC 12675' 12572' 17710'- 17830' MD; 9060.5' -9126' TVD 12618' 17940' - 18085' MD; 9190' - 9281' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 3, 2001 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 5/4/2001 10.7 Test Period >I 925 IFIow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 587 psi 24-Hour Rate > 4036 3735 7 28. CORE DATA ,, Bdef description of lithology, porosity, fractures, apparent dips and pressence of oik gas or water. Submit core chips. ~ ~.= (~ f~ ~V ~~''~ ..... ~L~'~ * This 10-407 is submitted as directed per the 10-401 form approved April 6, 2001 (Permit #201-029) ,,,~ ,~ ,~, ,, , Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ORIGiNAL -* GEOLOGIC MARKER,5 FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR, and time of each phase. Top H RZ 17270' 8856' Top of Kuparuk 17721' 9066' Top of Kuparuk lA 18465' 9552' 31. LIST OF ATTACHMENTS Summary of NK-07A Rig Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed L t ~L' ~, · ~ ,..----.-.--- Title BP Dr n,q En,q neer Date _June 7, 2001 Bill Isaacson Prepared by Paul Rauf 564-5799. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP EXPLORATION Page 1 of 1 Final Well i Event Summary Legal Well Name: NK-07 Common Well Name: NK-07A Event Name: REENTER+COMPLETE Start Date: 4/9/2001 End Date: DATE TMD 24 HOUR SUMMARY 4/9/2001 (ft) MIRU. Circ out freeze protect. 4/10/2001 (ft) Finish circ. ND tree, NU BOPE, POH LD tbg. 4/11/2001 (ft) Finish I_/D 4 1/2 tubing. RIH w/mill assy PUDP. CBU. POH 4/12/2001 (ft) Complete POH, set bridge plug, test csg, RIH w/whipstock. 4/13/2001 (ft) Mill window & formation. FIT. POH. PU directional BHA 4/14/2001 13,499.0 (ft) Finish RIH. Directionally drill 8 1/2" hole section. 4/15/2001 13,594.0 (ft) POH, test BOPE, RIH w/rotary steerable directional assy. 4/16/2001 14,917.0 (ft) Finish RIH, make M.A.D. pass, Drill 8 1/2" directional hole. 4/17/2001 16,451.0 (ft) Drilled f/14,917 t/16352. Short trip to 12,820. Drill to 16,451. 4/18/2001 17,214.0 (ft) Drill f/16,451 t/17,214. Test surface MWD. POH for failure. 4/19/2001 17,214.0 (ft) POH, change MWD and rotary steerable. RIH to 16,740. 4/20/2001 18,512.0 (ft) Ream to bottom from16,900. TD well at 18,512 measured depth. 4/21/2001 18,512.0 (ft) Short trip. Sweep hole. Spot liner pill. POH 4/22/2001 18,512.0 (ft) Break and grade bit. P/U casing equip. RIH with 4 1/2 liner. 4/23/2001 18,512.0 (ft) Run and cement 4 1/2 liner. Begin displacement to brine. 4/24/2001 18,512.0 (ft) Displace well. POOH. Test BOP's. Test casing. P/U perf. guns. 4/25/2001 18,512.0 (ft) Complete TIH with guns. Position guns. Slickline with Memory Gamma. 4/26/2001 18,512.0 (ft) Spot guns on depth. Perforate 4 1/2 liner. Circulate clean. POH. 4/27/2001 18,512.0 (ft) Complete laying down DP and guns. RIH with 4 1/2 tubing. 4/28/2001 18,512.0 (ft) Complete tubing trip. Land and circ. inhibitor. Attempt to set packer. 4/29/2001 18,512.0 (ft) Set and test packer/tubing. N/U and test tree. Freeze protect well. Printed: 6/6/2001 4:01:02 PM TREE = 4" C IW 1/B..LHEAD= FM( ACTUATOR= BAKER KB. ELEV = O9.1' BF. ELEV = 19.2' KOP = 950' Max Angle = 79 ~ 1436,~ Datum MD = 1727~' Datum 'FV'D= SS 8800' NK-07A SAFETY NOTES: 9-5,~" CSG SET ON B~ERGENCY SLIPS. OLD PERFS & LOWER 1452' OF PRB SDTRK TB6,CPKP/TP I:~A'D W/CMT. WB._L EXCEEDS 70 DEG t~ 12958'. 2o4~' ]-[4-1r~, .Es TRSSSV. D = 3.B19" ] GAS LIFT' MANDRELS Minimum ID - 3.725" @ 12662' 4-1/2" HES XN NIPPLE 9-5/8" X 7" BKR ZXP PKR/HANGER, ID = 6.300" H 7" HY DRIL 511 X 4-1/2" HY DRIL 521 XO, ID = 3.938" H 12572' 12678' PERF ORATi0 N: SuMMA RY' , R EF LOG: SWS GRICC L 04,'26/011: ANGLEAT Top F~RF: ~9 Note :Ref e [ to Ft:oducti0n DB for his tot ca perf data SEE :s'F¢; :' INTERVAL :::Opn/Sqz DATE 2.:34', 6 17710. 178~0 0 04~26/01 , , 2~4', ' - 6 '179:40 :. ieoe:5 0 o4¢ze~1 : 12641' 144-1/2" HES X NP, ID: 3.813" I 12662' I--~4-1/2" HESXNNIP, ID: 3.725" 12673' Id4-1/2" TBG, 12.6#, L-80 Nsc'r, ! .0152 bpf, ID= 3.958" 2s7s'I I 1',.4LLOU T'WIN DOw 1273'1,; 12747!; I 1759S' I--~ 4-1/2" MARKER JT (20') I 9-5/8" OBP H ITOPOFOLD CUT OFF 4-1/2" TBG H 12765' 13364' ITOPOF 7"LNR H 14791' 9-5/8" CSG, 47#, NT-80, .0732 bpf, ID = 8.681" H 7": I.N R, 29~, I._- 80 BTR S, 0.037:1 b pr, iD = 6:'184, :Id 14965' 15694': I 18512' DATE REV BY COMMENTS :DATE REV':BY COMIVENTS 0~/28~Q4 ::O:RIG NA L::C OMFLETIO N 04¢29,,'01 CH/lC-AK RIG SIDETRACK: 44-1/2" LNR, 12.6#, L-80 HYD521, ! .0152pbf, ID=3.918" PRUDHOE BAY UNIT wELL: NK- 07A :PERMIT No: 201;089 A F1 N o: 50- 02Q~22410' 01 t250':NSL 1099! "¢.tEL SBO. ::~, T12N; RiSE BP ExPlOration (A as ka) BP EXPLORATION Page 1 of 7 Operations Summa Report Legal Well Name: NK-07 Common Well Name: NK-07A Spud Date: 5/28/1994 Event Name: REENTER+COMPLETE Start: 4/9/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 14 Rig Number: Date From -To Hours Task Sub Phase Description of Operations Code 4/9/2001 09:00 - 16:00 7.00 MOB PRE PJSM. Cantilever derrick into transport position. Move off of NK 0SA. Do prep work around NK 07A. Move in rig & spot same on NK 7A. Shim rig, cantilever derrick into position and connect lines. Spot cuttings tank. ACCEPT rig at 1600 hrs April 9, 2001. 16:00 - 18:30 2.50 RIGU DECOMP !Take on Seawater. RU circ lines & test same to 3,500 psi. 18:30 - 20:30 2.00 RIGU DECOMP R/U Lubricator and attempt to pull BPV- No BPV. Handover indicated BPV. RD Lubricator. 20:30 - 00:00 3.50 CLEAN DECOMP PJSM. Reverse circulate 100 bbls of diesel from tubing. Change surface lines. Circulate out freeze protect conventionally. Con't circulating bottoms up. 4/10/2001 00:00 - 02:00 2.00 RIGU DECOMP PJSM. Circulate out freeze protect conventionally. Con't circulating bottoms up. 02:00 - 03:00 1.00 WHSUR DECOMP Install TWC & test same from below to 1,000 psi. O-K. 03:00 - 04:30 1.50 WHSUR DECOMP PJSM. Disconnect control line. ND tree. Check XO sub 4 1/2" x 5" DP ~n tbg hangeer. 04:30 - 06:30 2.00 BOPSUR DECOMP Nipple up BOP's, kill and choke lines. Flow line. 06:30 - 07:00 0.50 BOPSUR DECOMP PU test joint. RU lines to test BOP's 07:00 - 11:00 4.00 BOPSUR DECOMP PJSM. Test BOPE as per policy--250 psi for 5 min / 4,000 psi for 10 minutes. John Spalding with AOGCC waived witness of initial BOP test. 11:00 - 12:00 1.00 PULL DECOMP LD test equipment. RU 4 1/2" tubing handling equipment. Pull TWC. 12:00 - 12:30 0.50 PULL DECOMP MU landing jr, unseat tbg hanger. Observe well dead. Pull hanger to rig floor. 12:30 - 13:30 1.00 PULL DECOMP PJSM. LD landing jt & tbg hanger. RU spool for control line. 13:30 - 16:30 3.00 PULL DECOMP POH & LD 4 1/2" tbg to TRSSSV. RD control line spooling equipment. Recover 61 ss bands. 16:30 - 00:00 7.50 PULL DECOMP Con't POH laying down 4 1/2" tubing. 4/11/2001 00:00 - 02:30 2.50 PULL DECOMP Complete POH LD 4 1/2" tubing. Total 324 jts & 21.58' cut off recovered. Jet cut belled. Tubing in good condition, NORM readings 3-3.5 Rem. 02:30 - 03:30 1.00 PULL DECOMP PU & run test plug, pressure lower pipe rams to BP & AOGCC regulations. Pull & LD test plug. 03:30 - 04:00 0.50 PULL DECOMP Install wear bushing. 04:00 - 06:00 2.00 PULL DECOMP Clear floor. PU Baker mill assy. 06:00 - 09:00 3.00 CLEAN DECOMP PJSM. MU & RIH w/mill assy BHA. 09:00 - 17:00 8.00 CLEAN DECOMP PU & RIH w/5" DP from pipe shed. Drift same. (SLM off critical path) 17:00 - 19:00 2.00 CLEAN DECOMP .Con't RIH w/mill assy on 5" DP out of derrick. Tag tubing stump @ 13,359 ft - Drillers depth. Break circulation. Establish downhole parameters for upcoming milling operations. 19:00 - 21:00 2.00 CLEAN DECOMP Circulate well clean @ 9 BPM w/800 psi. Observe well dead. 21:00 - 00:00 3.00 CLEAN DECOMP POH w/milling assy on 5" DP 4/12/2001 00:00 - 02:00 2.00 CLEAN DECOMP Con't POH w/8" x 8 1/2" mill assy on 5" DP. 02:00- 04:00 2.00 CLEAN DECOMP PJSM. LD BHA. Clear floor. 04:00 - 04:30 0.50 CLEAN DECOMP Service rig / top drive. 04:30 - 05:30 1.00 CLEAN DECOMP Rig up Schlumberger electric line. 05:30 - 10:30 5.00 CLEAN DECOMP PJSM. Correlate & set bridge plug @ at 12,765 ft loggers depth. 10:30 - 11:00 0.50 CLEAN DECOMP Rig down Schlumberger electric line. 11:00 - 12:00 1.00 CLEAN DECOMP ~ PJSM. Pressure test casing 300 psi / 3,700 psi for 30 mins. Total 12.4 bbls pumped / returned. 12:00 - 21:00 9.00 STWHIP LNR1 PJSM. MU & RIH w/9 5/8" Bottom set / one trip whip stock assy and window mills. Shallow test MWD O-K. Fill pipe every 30 stands. 21:00 - 22:00 1.00 STWHIP LNR1 Orient & set whipstock w/anchor @ 12,755 ft Drillers depth. Shear anchor w/18,000 lbs. Shear mills w/40,000 lbs. Printed: 5/1/2001 10:32:54 AM BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: NK-07 Common Well Name: NK-07A Spud Date: 5/28/1994 Event Name: REENTER+COMPLETE Start: 4/9/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 14 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 4/12/2001 22:00 - 00:00 2.00 STKOH LNR1 PJSM. Displace well with 9.4 ppg LSND mud. '~ 4/13/2001 00:00 - 01:00 1.00 STWHIP LNR1 Displace brine in well with 9.4 ppg LSND mud. 01:00 - 10:00 9.00 STWHIP LNR1 Mill 9 5/8" casing window from 12,731' to 12,747' and new hole to 12,767'. Ream through window several times. 10:00 - 13:00 3.00 STWHIP LNR1 Circulate & condition mud. Pump high weight high vis sweep. Perform LOT of 12.54 ppg EMW. 13:00 - 15:00 2.00 STWHIP LNR1 Flow check. Pump dry job. POH w/window mills. 15:00 - 16:00 1.00 STWHIP LNR1 PJSM. Slip & cut drlg line. 16:00 - 18:30 2.50 STWHIP LNR1 Con't POH wi window mills. 18:30 - 20:30 2.00 STWHIP LNR1 LD milling BHA. Mills in gauge. 20:30 - 21:00 0.50 STWHIP LNR1 Jet wash BOP's. Clear floor. 21:00 - 23:30 2.50 DRILL LNR1 PJSM. MU 8 1/2" PDC bit on directional BHA. Shallow test MWD. 23:30 - 00:00 0.50 DRILL LNR1 RIH w/8 1/2" bit. 4/14/2001 00:00 - 04:30 4.50 STWHIP LNR1 RIH with 8 1/2" bit and drilling BHA fill pipe every 35 stands. 04:30 - 05:00 0.50 STWHIP LNR1 Perform LOT with EMW of 12.54 ppg. 05:00 - 06:00 1.00 STWHIP LNR1 Orient tool and go through 9 5/8" casing window. 06:00 - 00:00 18.00 DRILL LNR1 Drill 8 1/2" directional hole 12,767 ft to 13,499 ft. ADT - 12.5 hrs, AST - 8.25 hrs, ART - 4.25 hrs. 4/15/2001 00:00 - 01:30 1.50 DRILL LNR1 Directionally drill 8 1/2" hole 13,499 ft to 13,594 ft. ADT - 1.5 hrs, ART - 1.5 hrs. 01:30 - 03:00 1.50 DRILL LNR1 Circulate hole clean. PJSM for trip out of hole. 03:00 - 10:00 7.00 DRILL LNR1 Flow check. POH w/8 1/2" bit. 10:00 - 11:30 1.50 DRILL LNR1 Flow check. PJSM. LD BHA. Clear floor. 11:30- 12:00 0.50 DRILL LNR1 Pullwear bushing. 12:00 - 16:00 4.00 DRILL LNR1 PJSM. PU test plug/joint. Test BOP's as per policy--250 psi for 5 min / 4,000 psi for 10 minutes. Choke manifold & safety valves tested off critical path. Jeff Jones with AOGCC waived witness of test. 16:00 - 16:30 0.50 DRILL LNR1 , LD test plug /joint. Install wear bushing. 16:30 - 19:00 2.50 DRILL LNR1 ~PJSM. MU 8 1/2" PDC bit on Rotary steerable BHA. Shallow test MWD. O-K. 19:00 - 23:00 4.00 DRILL LNR1 RIH w/8 1/2" bit on 5" DP from pipe shed. 23:00 - 00:00 1.00 DRILL LNR1 Con't RIH w/8 1/2" bit on 5" DP from derrick. 4/16/2001 00:00 - 03:00 3.00 DRILL LNR1 Con't RIH w/8 1/2" bit on 5" DP to 12,524 ft. 03:00 - 05:00 2.00 DRILL LNR1 Circulate well. PJSM slip & cut drlg line. Service rig. Establish baseline 3arameters. 05:00-06:30 1.50 DRILL LNR1 Make M.A.D. pass 12,530 ft - 12,780 ft, 13,125 ft - 13,170 ftw/pumps off. 06:30 - 07:30 1.00 DRILL LNR1 Circulate bottoms up. 07:30 - 08:00 0.50 DRILL ~LNR1 Downlink Rotary Steerable tool. 08:00- 12:30 4.50 DRILL LNR1 Drill 8 1/2" hole 13,594 ft to 14,054 ft. ADT- 2 hrs 12:30 - 14:00 1.50 DRILL CIRC LNR1 Change swab & liner in #1 mud pump. Circulate hole w/hi vis, weighted sweep. (30 minutes spent to cut out bolts) 14:00 - 16:00 2.00 DRILL LNR1 Drill 8 1/2" hole 14,054 ft to 14,200 ft. ADT - 1 hrs 16:00 - 17:00 1.00 DRILL CIRC LNR1 Change liner gasket on #1 mud pump. Circulate hole. 17:00 - 00:00 7.00 DRILL LNR1 Drill 8 1/2" hole 14,200 ft to 14,917 ft. ADT - 5 hfs 4/17/2001 00:00 - 14:30 14.50 DRILL LNR1 Drill 8 1/2" directional hole 14,917 ft to 16,352 ft. WOB-11-15 RPM=120 GPM-570 PS1=2850 ADT= 8.5 hrs. Drilling break at 15,850' and 15,950'. Flow check. NO flow, continue drilling. Mud gas cut and reduced weight to 8.0 ppg. Increase mud weight to 10.0 ppg while drilling. 14:30 - 16:30 2.00 DRILL LNR1 Circulate hole clean prior to short trip, with 10 ppg. mud. Flow check. OK Printed: 5/1/2001 10:32:5,4 AM BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: NK-07 Common Well Name: NK-07A Spud Date: 5/28/1994 Event Name: REENTER+COMPLETE Start: 4/9/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 14 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 4/17/2001 14:30 - 16:30 2.00 DRILL LNR1 16:30 - 21:00 4.50 DRILL LNR1 Short trip from 16,352' to 12,820'. No adverse hole conditions or fill. (Flow check at shoe---static, hole taking proper fill.) 21:00 - 23:00 2.00 DRILL LNR1 Ream last stand to bottom. Downlink tool, pump up survey. Circ. up air from pipe fill. 23:00 - 00:00 1.00 DRILL LNR1 Drilling from 16,352' to 16,451'. 4/18/2001 00:00 - 10:00 10.00 DRILL LNR1 Drilling from 16,451 to 17,214 in "Tuff formation". RPM-- 120 GPM= 550 @ 2900 PSI WOB=5-15 MWD failure. 10:00 - 15:30 5.50 DRILL LMWD LNR1 Trouble shoot and test surface equipment.(Clean pump screens, adjust charge on pulsation dampners, etc., etc.) Attempt to down link MWD--- to no avail. Loss of signal. 15:30 - 19:30 4.00 DRILL LMWD LNR1 Observe well. POH to shoe. 19:30 - 20:30 1.00 DRILL LMWD LNR1 Pump up signal from MWD. (Intemittent and unreliable) Observe well. 20:30 - 00:00 3.50 DRILL LMWD LNR1 POH for MWD failure, to 4600. 4/19/2001 00:00 - 03:30 3.50 DRILL BHA LNR1 POH for MWD failure. Lay down 129 jts 5" drill pipe. 03:30 - 05:30 2.00i DRILL BHA LNR1 Lay down BHA. Clean, inspect and grade bit. Will re-run bit. Has very minimal chipping to a few of the cutters. 05:30 - 06:00 0.50 DRILL BHA LNR1 Service rig. 06:00 - 09:00 3.00 DRILL BHA LNR1 Make up BHA. Program Rotary Steerable tool and test. 09:00 - 10:30 1.50 DRILL BHA LNR1 Make up MWD. PJSM prior to installing RA source. RIH BHA and shallow test. 10:30 - 17:30 7.00 DRILL BHA LNR1 RIH, picking up 5" drill pipe from pipe shed. RIH from derrick to window. 17:30 - 18:30 1.00 DRILL BHA LNR1 Cut drilling line. ;18:30 - 20:00 1.50 DRILL BHA LNR1 Circulate bottoms up to reduce ECD's once on bottom. Stage pumps up to 520 gpm @ 2700 with a 12 ECD. 20:00 - 22:00 2.00 DRILL BHA LNR1 RIH to 15,964 for benchmark survey 22:00 - 23:00 1.00 DRILL BHA LNR1 Benchmark survey MWD at 15,964. (Ream and wash hole prior to survey, due to sticky conditions.) 23:00 - 23:30 0.50 DRILL BHA LNR1 RIH from 15,964 to 16,740. Hole conditons deteriorating. 23:30 - 00:00 0.50 DRILL BHA LNR1 Ream from 16,740 to 16,900. 4/20/2001 00:00 - 01:30 1.50 DRILL BHA LNR1 Ream from 16,740 to 17,214. Pump up surveys. 01:30 - 22:00 20.50 DRILL LNR1 Drilling from 17,214 to 18,512. Drilling parameters: WOB'-15-25 540 ~GPM @ 2900 PSI TORQUE=26,000 on bottom. Pumping weighted barafibre sweeps to assist cuttings removal. 22:00 - 00:00 2.00 DRILL LNR1 Pump weighted sweep S-S. Observe well. Prepare for shor[ trip. 4/21/2001 00:00 - 02:30 2.50 DRILL LNR1 Wiper trip to 16,488. Intermittent overpull of 15-25k on first 500 ft. off bottom. No adverse hole conditions or fill on trip back in hole. 02:30 - 06:00 3.50 DRILL LNR1 Circulate Sweep surface to surface. Spot app. 410 bbls. liner running 3ill treated with additional 5% of torq trim. Observe well. Prepare for trip out of hole. 06:00 - 12:00 6.00 DRILL ~LNR1 POH to 12,500, with no adverse hole conditons. Hole taking proper displacement. 12:00 - 13:00 1.00 DRILL LNR1 Slip and cut drilling line. 13:00 - 21:00 8.00 DRILL LNR1 POH laying down last 56 stands of drillpipe. 21:00 - 00:00 3.00 DRILL LNR1 PJSM. POH laying down BHA, including nuclear source and rotary steerable. 4/22/2001 00:00 - 01:00 1.00 DRILL LNR1 Break and grade bit. Lay down all excess equipment and prepare for next operation. 01:00 - 02:00 1.00 CASE LNR1 Rig up casing equipment, verify pipe count in shed. 02:00 - 14:30 12.50 CASE LNR1 P/U shoe track and check floats. RIH with 4 1/2 hydril 521 liner using collar clamp and nubbins. P/U 2 jts. 7", and rig up false floor etc.. to handle 2 7/8 EUE pipe. M/U 3 jts., 2 7/8 stinger extension and pick up Printed: 5/1/2001 10:32:54 AM BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: NK-07 Common Well Name: NK-07A Spud Date: 5/28/1994 Event Name: REENTER+COMPLETE Start: 4/9/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 14 Rig Number: Date From-To Hours Task Sub Code Phase Description of Operations 4/22/2001 02:00 - 14:30 12.50 CASE LNR1 liner hanger. 14:30 - 15:30 1.00 CASE LNR1 Circulate liner volume. 15:30 - 21:00 5.50 CASE LNR1 RIH with 4 1/2 liner to 12,689. 21:00 - 23:00 2.00 CASE LNR1 Circulate and condition mud at window. P/U and stand back cement head in derrick. Record up/down and rotating torque. UP=185 DOWN=145 Torque=4,000. 23:00 - 00:00 1.00 CASE LNR1 Run into open hole from 12,689 to 13,500. 4/23/2001 00:00 - 02:30 2.50 CASE LNR1 Run 4 1/2" 12.6# L-08 HYD 521 liner on 5" drill pipe from 13,500 to 15,940'. 02:30 - 03:00 0.50 CASE LNR1 Wash and ream from 15,940 to 16,075. Reaming with 8,000 to 9,500 torque at 20 RPM. Pumping with 335 GPM @ 1275 PSI. 03:00 - 04:00 1.00 CASE LNR1 Wash and circulate liner down from 16,075 to 16,648'. 04:00 - 05:00 1.00 CASE LNR1 RIH with liner from 16,648' to 17,573' 05:00 - 08:30 3.50 CASE LNR1 Wash liner down from app. 200 ft. above top of the Kuparuk. Done as a precaution only-hole did not dictate need. Wash remaining stands to bottom at 18,512.( Pump rate at 250 GPM while washing across the Kuparuk.) 08:30 - 11:00 2.50 CASE LNR1 Stage pumps up to 8.5 BPM with 1400 psi. 11:00 - 11:30 0.50 CASE LNR1 Make up cement head and lines. 11:30 - 14:00 2.50 CASE LNR1 Circulate. Increase rate to 10 BPM @ 1810 psi. Held PJSM with rig crew, cementing crew and truck drivers. Focus on fluid transfers. Check your equipment and know your volumes. 14:00 - 15:30 1.50 CASE LNR1 Test cementing lines with 4000 psi. Pump 70 bbl chemical wash and 30 bbl Mud Push at 12.0 ppg, followed by 176 bbls class 'G' cement at 15.8 ppg. Drop pipe wiper dart. 15:30 - 16:00 0.50 CASE LNR1 Displace with 135 bbl perf pill and 169 bb110.0 ppg mud at 10 BPM. Good indication of dart latching liner wiper plug. Bump plug with 2800 psi. Floats held. 16:00 - 16:30 0.50 CASE LNR1 Set ZXP liner top packer with 70K lbs down weight. Good indication of packer setting. 16:30 - 17:30 1.00 CASE LNR1 Circulate bottoms up. No cement returns. 17:30 - 18:00 0.50 CASE LNR1 Test liner top packer to 2,000 for 10 minutes. Good test. 18:00 - 19:30 1.50 CASE LNR1 Wait for 10 ppg. brine to arrive on Ioction. Peak unable to supply enough trucks to perform cement job in tandem with displacement. (Many trucks busy hauling mud for 33-E) 19:30 - 00:00 4.50 CASE LNR1 Displace well to seawater as follows: Pump 20 bbls. caustic wash, 25 bbls. Hi Vic. spacer, 50 bbls. Baraklean FL sweep, 25 bbls. Hi Vis. spacer. Chase with a minimum of two hole volumes of seawater ~followed by 10 ppg. brine. 4/24/2001 00:00 - 03:00 3.00 CASE LNR1 'Continue displacing well to 8.5 seawater. Pumped a total of 1,800 bbls. Flush all surface equipment and lines. 03:00 - 07:00 4.00 CASE LNR1 Displace sea water with 10.0 ppg brine pumping at 8-10 BPM Obtain 100 NTU on brine coming out. Pump dry job. Observe well. 07:00 - 08:00 1.00 CASE LNR1 Rig down cement head and make service breaks. Break down and lay down all equipment invloved in displacement operation. Lay down all excess equipment from rig floor. 08:00 - 09:00 1.00 CASE LNR1 Slip and cut drilling line. 09:00 - 14:00 5.00 CASE LNR1 POOH with liner running tool and 2 7/8" stinger extension. Hole took proper displacement. 14:00 - 14:30 0.50 CASE LNR1 Lay down liner running tool and 3 joints 2 7/8" stinger. Inspect running tool and plug carrier for missing parts---none missing! 14:30 - 15:00 0.50 CASE LNR1 Pull bowl protector. 15:00 - 20:00 5.00 BOPSUR LNR1 Test BOP as per BP policy, 5 minute Iow---10 minute high. Witness of Printed: 5/1/2001 10:32:54 AM BP EXPLORATION Page 5 of 7 Operations Summary Report Legal Well Name: NK-07 .Common Well Name: NK-07A Spud Date: 5/28/1994 Event Name: REENTER+COMPLETE Start: 4/9/2001 End: .Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 14 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 4/24/2001 15:00 - 20:00 5.00 BOPSUF LNR1 BOP test waived by AOGCC Rep. "Chuck Scheve". 20:00 - 20:30 0.50 CASE LNR1 Install bowl protector. Lay down test joint and remainder of testing equipment. Test casing to 3700 psi for 30 minutes---Good test. 20:30 - 21:00 0.50 CASE LNR1 PJSM with Halliburton perforating crew and all rig personnel. R/U to run guns. 21:00 - 00:00 3.00 CASE LNR1 Pick up 9 perf. 2 3/4" guns. Change handling equipment. R/U stack power tongs. RIH with 2 7/8" DP lxl to 850'. 4/25/2001 00:00 - 06:00 6.00 CASE LNR1 RIH with 2 3/4" guns on 2 7/8" DP to 5870. Pick up 177 jts from pipe shed. 06:00 - 07:00 1.00 CASE LNR1 Make up R'[TS packer, jars,circulating valve and tools. 07:00 - 17:00 10.00 CASE LNR1 RIH with 5" drill pipe. Go through top of liner with no problems. Tag up Landing Collar at @ 18,393 Drilller's depth. 17:00 - 18:00 1.00 CASE LNR1 POH back to 18,100 and position pipe for wireline "Memory Gamma". 18:00 - 22:00 4.00 CASE LNR1 RIH with Memory Gamma tool on slick line. Log up from 13,000 to 12,590 at 60 FPM. Log tie in questionable. 22:00 - 00:00 2.00 CASE LNR1 Re-run Memory Gamma at slower logging speed from 13,000 to 12,590 at 30 FPM. 4/26/2001 00:00 - 02:30 2.50 CASE LNR1 Run memory log #2, logging from 13,000 to 12,590. 02:30 - 07:00 4.50 CASE LNR1 Reverse out 10.9 perf. pill from above ported sub. Pressures limited to 1000 PSI by Halliburton "perf. gun rep." Rates while circulating: Initial rate of 1 bbl. per minute at 750 .... Final rate 2.5 bbls. @ 975. 07:00 - 08:30 1.50 CASE LNR1 Spot 105 bbls. diesel down drill pipe to achieve 500 pound underbalance for perforating the well. 08:30 - 09:30 1.00 CASE LNR1 Pressure test lines to 3,500. Set packer. Close bag and pressure annulus up to 400. Trap annulus pressure and apply 3500 psi down drill pipe. Release pressure and wait for guns to shoot. Good indications of guns firing @ 9:15, immediate strong blow at surface. 09:30 - 12:00 2.50 CASE LNR1 Circ. two drill pipe volumes while holding back pressure on choke until diesel is removed. Observe well for flow. Well static. Continue circulation through open choke. Noted some oil and gas with first bottoms up. 12:00 - 12:30 0.50 CASE LNR1 Observe well for flow. Release packer. Well static. 12:30 - 15:30 3.00 CASE LNR1 Circulate well the long way and observe bottoms up for gas/oil. Spot 25 bbls. perf. pill on bottom. 15:30 - 17:30 2.00 CASE LNR1 POH lxl to 16,210. Hole taking proper displacement. 17:30 - 18:30 1.00 CASE LNR1 Cut drilling line. Pump dry job. 18:30 - 00:00 5.50 CASE LNR1 POH lxl with 2 3/4 gun. 4/27/2001 00:00 - 05:00 5.00 CASE LNR1 POH laying down 5" drill pipe and Halliburton packer, safety jr. and tools. 05:00 - 12:30 7.50 CASE LNR1 POH laying down all 2 7/8 D.P., circ. sub and cross overs. 12:30 o 14:00 1.50 CASE ~LNR1 PJSM POH laying down perf. guns. - .... Guns all fired. 14:00 - 14:30 0.50 CASE LNR1 . Clear floor of all excess equipment. Prepare floor for next operation. 14:30 - 15:00 0.50 RIGU COMP Rig up casing equipment to run 4 1/2 NSCT, 12.6#, tubing. 15:00 - 15:30 0.50 RUNCOI~ COMP Pull wear ring. 15:30 - 00:00 8.50 RUNCOIt COMP Trip in hole with 4 1/2 NSCT, 12.6 # L-80 tubing and completion assembly. Proper displacement on trip in hole. 4/28/2001 00:00 - 02:00 2.00 RUNCOIt COMP Trip in hole with 4 1/2 NSCT, 12.6 # L-80 tubing and completion assembly. Proper displacement on trip in hole. 02:00 - 03:00 1.00 RUNCOr COMP Make up TRSSSV control line and test to 5000 psi. 03:00 - 05:30 2.50 RUNCOr COMP Trip in hole with 4 1/2 NSCT, 12.6 # L-80 tubing and completion assembly with control line. Proper displacement on trip in hole. 05:30 - 06:30 1.00 RUNCO~ COMP RIH and tag up on 7x4 1/2 liner crossover at 12,678'. Space out and M/U tubing hanger. Printed: 5/1/2001 10:32:5,4AM BP EXPLORATION Page 6 of 7 Operations Summary Report Legal Well Name: NK-07 Common Well Name: NK-07A Spud Date: 5/28/1994 Event Name: REENTER+COMPLETE Start: 4/9/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 14 Rig Number: Sub Date From -To Hours Task Code Phase Description of Operations 4/28/2001 06:30 - 07:30 1.00 RUNCOI~ COMP Attach and test control lines to tubing hanger for 15 minutes @ 5000. Good test. 07:30 - 08:00 0.50 RUNCOI~ COMP Land tubing and RILDS. 08:00 - 12:00 4.00 RUNCOI~ COMP Reverse in inhibitor treated brine at 3 bpm. 12:00 - 14:00 2.00 RUNCOI~ COMP Drop ball and attempt to pressure up on tubing and set packer. Ball is not on seat. Attempt to circ. ball to seat---to no avail. 14:00 - 18:00 4.00 RUNCOI~THR COMP Wait for slick line unit to arrive on location to push ball/bar to seat. 4/29/2001 01:00 - 02:30 1.50 RUNCOI~ COMP Pressure up and set packer to 3,700 and hold tubing test for 30 minutes. Bleed tubing pressure to 1,500 and test packer to 3,700 for 30 minutes.(tubing pressure @ 2250 during packer test) Bleed tubing and observe RP shear. Bleed all pressures to zero. 02:30 - 03:00 0.50 RUNCOI~q COMP Install 2 way check valve and test from below to 3,700. 03:00 - 05:00 2.00 BOPSUF COMP Nipple down BOP equipment. 05:00 - 07:30 2.50 BOPSUF COMP Attach control lines to tubing hanger. Nipple up tree. 07:30 - 08:30 1.00; BOPSUF COMP Pressure test tree and adapter flange to 5,000 for 10 minutes. 08:30 - 09:30 1.00 BOPSUF COMP Remove 2 way check valve with DSM, using lubricator. 09:30 - 12:30 3.00i BOPSUF COMP Freeze protect well to 3,700 with 260 bbls. diesel. Hot oil heating diesel while pumping down hole. 12:30 - 16:00 3.50i BOPSUF COMP U-tube diesel from annulus to tubing. Clean pits of all excess fluids. Ready rig for move. 16:00 - 16:30 0.50 BOPSUF COMP Pressure test SSS¥ from below to 1000. 16:30 - 17:00 0.50 BOPSUF COMP Remove double annulus valve. Prepare tree for production group. Secure well. Rig released from NK-07A @ 1700 hours. Printed: 5/1/2001 10:32:54AM BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: NK-07 Common Well Name: NK-07A Spud Date: 5/28/1994 Event Name: REENTER+COMPLETE Start: 4/9/2001 End: Contractor Name: DOYON Rig Release: Group: SLIC Rig Name: DOYON 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/28/2001 18:00 - 21:30 3.50 RUNCOr~OTHR COMP PJU slickline with riser and extension to accommodate any well control issues. 21:30 - 23:00 1.50 RUNCOI~OTHR COMP RIH with slickline to chase ball to seat. No signs of tagging ball on TIH to 12,666 WLM. Pick up to 12,625 and wait for rig to pressure up on ball. 23:00 - 23:30 0.50 RUNCOI~OTHR COMP Pressure up on tubing and observe 200 PSI buildup on tubing with no returns up annulus. Ball is on seat. 23:30 - 00:00 0.50 RUNCOr~THR COMP POH with slickline "Blind Box" tool. 4/29/2001 00:00 - 01:00 1.00 RUNCOI~OTHR COMP POH with slickline "Blind Box" tool and rig down. Printed: 5/1/2001 10:32:5,4AM ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : Niakuk Well ..................... : NK-07A API number ............... : 50-029-22410-01 Engineer ................. : B. Barnes COUNTY: .................. : Doyon 14 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller's Tally GL above permanent ....... : 21.29 ft KB above permanent ....... : -999.25 ft DF above permanent ....... : 52.65 ft . Vertical section origin Latitude (+N/S-) ......... : 0.00 ft Departure (+E/W-) ........ :. 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 284.65 degrees 21-Apr-2001 16:46:53 Pa~e" 1 of 9 Spud date ................ : 12-Apr-01 Last survey date ......... : 21-Apr-01 Total accepted surveys...: 216 MD of first survey ....... : 0.00 ft MD of last survey ........ : 18512.00 ft Geomagnetic data - Magnetic model ........... : BGGM version 2000 Magnetic date ......... '...: 12-ADr-2001 Magnetic field strength..: 1150.14 HCNT Magnetic dec (+E/W-) ..... : 27.00 degrees Magnetic dip ............. : 80.87 degrees MWD survey Reference Criteria' ~ Reference G .............. : 1002.68 mGal Reference H .............. : 1150.14 HCNT Reference Dip ............ : 80.87 degrees Tolerance of G.. ......... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 27.00 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.00 degrees (Total az corr = magnetic dec - grid conv) Sag applied (y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 21-Apr-2001 16:46:53 Page 2 of 9 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 1 0.00 0.00 0.00 2 94.05 0.52 19.91 3 194.05 0.69 328.98 4 294.05 0.74 314.34 5 394.05 1.64 321.23 6 494.05 1.89 308.44 7 594.05 3.07 313.02 8 694.05 5.38 304.51 9 794.05 7.88 304.77 10 844.05 8.76 305.03 11 894.05 9.31 305.62' 12 944.05 10.19 306.42 13 994.05 11.08 307.09 14 1044.05 11.74 307.04 15 1094.05 12.81 304.77 16 1144.05 13.58 304.09 17 1194.05 14.10 303.40 18 1244.05 14.39 304.84 19 1294.05 15.15 307.33 20 1344.05 16.26 309.48 21 1394.05 17.33 311.32 22 1444.05 18.72 312.06 23 1494.05 19.32 310.76 24 1544.05 19.92 310.45 25 1594.05 19.93 310.96 26 1644.05 19.27 .310.95 27 1694.05 18.83 310.27 28 1744.05 18.94 309.73 29 1794.05 19.76 307.98 30 1844.05 20.41 310.69 Course TVD Vertical Displ Displ Total length depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) (ft) 0.00 0.00 0.00 0..00 0.00 0.00 94.05 94.05 -0.04 0.40 0.15 0.43 100.00 194.04 0.35 1.34 -0.01 1.34 100.00 294.04 1.34 2.31 -0.78 2.44 100.00 394.01 3.05 3.88 -2.14 4.43 100.00 493.97 5.71 6.02 -4.33' 7.41 100.00 593.87 9.58 8.87 -7.58 11.67 100.00 693.59 16.34 13.36 -13.40 18.92 100.00 792.92 27.19 19.92 -22.89 30.35 50.00 842.39 33.98 24.06 -28.83 37.55 50.00 891.77 41.32 28.60 -35.23 45.38 50.00 941.05 49.21 33.58 -42.08 53.84 50.00 990.19 57.75 39.11 -49.47 63.06 50.00 1039.20 66.90 45.07 -57.37 72.95 50.00 1088.06 76.81 51.29 -65.98 83.57 50.00 1136.74 87.55 57.75 50.00 1185.28 98.85 64.39 50.00 1233.75 110.45 71.29 50.00 1282.09 122.31 78.80 50.00 1330.23 134.69 87.22 50.00 1378.09 147.70 96.58 50.00 1425.64 161.48 106.88 50.00 1472.91 176.03 117.65 50.00 1520.01 191.12 128.58 50.00 1567.01 206.43 139.69 50.00 1614.12 221.47 15'0.68 50.00 1661.38 236.14 161.31 50.00 1708.69 250.76 171.71 50.00 1755.86 265.87 182.10 50.00 1802.82 281.47 192.98 -75.39 -85.34 -95.52 -105.82 -116.42 -127.41 -138.96 -151.19 -163.93 -176.85 -189.52 -201.91 -214.30 -227.21 -240.48 At DLS Azim (deg/ (deg) 100f) 0.00 0.00 19.91 0.55 359.56 0.54 341.29 0.19 331.10 0.91 324.28 0.47 319.50 1.'20 314.91 2.39 311.03 2.50 309.85 1.76 303 .~7 1.12 308.59 1.78 308.33 1.80 308.16 1.32 307.86 2.35 94.97 106.91 119.19 131.94 145.46 307.45 1.57 307.03 1.09 306.73 0.92 306.67 1.98 306.84 2.51 159.88 175.31 191.57 208.34 225.36 307.16 2..39 307.56 2.82 307.89 1.47 308.11 1.22 308.30 0.35 242.12 258.43 274.61 291.17 308.34 308.49 1.32 308.62 0.99 308.70 0.41 308.71 2.01 308.75 2.27 Srvy tool type TIp Tool qual type [(c)2001 Anadrill IDEAL ID6_lC_08] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) . (deg) (ft) (ft) 31 1894.05 2.1.30 310.29 50.00 1849.55 32 1944.05 22.13 310.19 50.00 1896.00 33 1994.05 23.53 309.87 50.00 1942.08 34 2044.05 24.60 309.30 50.00 1987.73 35 2094.05 25.16 311.08 50.00 2033.09 36 2144.05 26.42 309.39 50.00 2078.11 37 2194.05 27.66 309.83 50.00 2122.65 38 2244.05 29.50 310..11 50.00 2166.55 39 2294.05 31.35 310.73 50.'00 2209.66 40 2344.05 32.52 310.25 .50.00 2252.10 41 2394.05 34.04 308.60 50.00 2293.90 42 2444.05 34.96 307.06 50.00 2335.10 43 2494.05 36.54 306.06 50.00 2375.68 44 2544.05 38.58 306.95 50.00 2415.31 45 2594.05 40.44 307.61 50.00 2453.89 46 2644.05 42.55 306.80 50.00 2491.34 47 2694.05 43.92 308.06 50.00 2527.76 48 2744.05 45.15 307.98 50.00 2563.40 49 2794.05 45.15 310.02 50.00 2598.67 50 2894.05 .49.01 309.92 100.00 2666.75 51 2994.05 53,11 311.51 52 3094.05 56.00 308.60 53 3194.05 56.30 311.42 54 3294.05 58.90 309.64 55 3394.05 60.11 312.47 56 3494.05 60.06 310.59 57 3594~05 61.89 309.17 58 3694.05 61.94 308.87 59 3794.05 61.25 310.49 60 3894.05 60.83 311.64 100.00 100.00 100.00 ,100.00 100.00 100.00 100.00 100.00 100.00 100.00 2729.59 2787.59 2843.30 2896.88 2947.63 2997.51 3046.02 3093.10 3140.68 3189.10 21-Apr-2001 16:46:53 Page 3 of 9 Vertical Displ Displ Total At' DLS Srvy Tool section +N/S- +E/W- displ 'Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 297.49 204.54 -254.02 326.13 308.84 314.17 216.49 -268.14 344.62 308.92 331.70 228.97 -282.99 364.02 308.98 350.19 241.96 -298.71 384.41 309.01 369,17 255.53 -314.77 405.44 309.07 388.79 269.58 -331.38 427.18 309.13 409.39 284.07 -348,89 449.91 309.15 431.01 299.44 -367.22 473.83 309.19 453.81 315.85 -386.50 499.14 309.26 .477.62 333.03 -406.61 525.58 - 309.32 502.53 350.44 -427.81 528.56 367.81 -450.18 555.67 385.20 -473.64 583.95 403.34 -498.14 613.31 422.61 -523.44 643.90 ' 442.63 -549.83 675.48 463.45 -577.02 707.67 485.05 -604.65 739.96 507.36 -632.19 806.14 554.39 -688.31 875,98 605.13 -747,23 949.56 657.52 -809.59 1024.60 710.91 -873.19 1100.56 765.75 -937.36 '~1177.72 822.34 -1002.32 1255.02 1334.12 1414.48 1494.18 1572.54 553.02 581.33 610.51 640.95 672.75 705.86 740.10 775.16 810.60 883.81 961.53 1042.96 1125.98 1210.38 1296.49 1383.11 1470.54 1558.76 1646.72 1734.18 309.32 309.25 309.12 309.00 308.92 308.84 308.77 308.74 308.75 308.85 309.00 309.08 309.15 309.25 309.37 309.50 309.52 309.50 309.51 309.58 879.81 -1067.20 935.86 -1134.30 991.41 -1202.85 1047.56 -1270.54 1105.04 -1336.51 1.80 1.66 2.81 2.19 1.87 2.92 2.51 3.69 3.75 2.39 3.54 2.54 3.37 4.22 3.81 4.35 3.24 2.46 2.89 3,86 4.28 3.74 2.36 3.00 2.72 1.63 2.21 0.27 1.58 1.09 MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 21-Apr-2001 16:46:53 Page 4 of 9 Seq MeasUred Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 61 3994.05 63.05 311.57 100.00 3236.13 1651.19 1163.63 -1402.49 1822.37 309.68 2.22 MWD_M 62 4094.05 62.98 313.02 100.00 3281.51 1730 13 1223.59 -1468.41 1911.39 309.80 1.29 MWD_M 63 4194.05 63.28 314.35 100.00 3326.71 1808.12 1285.21 -1532.91 2000.39 309.98 1.22 MWD_M 64 4294.05 64.07 314.98 100.00 3371.05 1885.73 1348.21 -1596.66 2089.73 310.18 0.97 MWD_M 65 4394.05 63.08 313.99 100.00 3415.56 1963.41 1410.96 -1660.54 2179.04 310.35 1.33 MWD_M ~--~ 66 4494.05 61.85 312.24 100.00 3461.79 2041.35 1471.57 -1725.26 2267.61 310.46 1.98 MWD_M 67 4594.05 60.32 313.16 100.00 3510.14 2118.60 1530.92 -1789.59 2355.07 310.55 1.73 MWD_M 68 4694.05 61.47 314.93 100.00 3558.78 2194.72 1591.67 -1852.38 2442.28 310.67 1.93 MWD_M 69 4794.05 62.45 312.17 100.00 3605.80 2271.98 1652.46 -1916.35 2530.42 310.77 2.63 MWD_M 70 4894.05 61.23 309.43 100.00 3653.00 2351.10 1710.07 -1983.07 2618.57 310.77 2.71 MWD_M 71 4994.05 61.46 308.66 100.00 3700.95 2431.02 1765.35 -2051.22 2706.28 310.72 0.71 MWD_M 72 5094.05 61.21 309.36 100.00 3748.92 2510.95 1820.58 -2119.40 2793.99 310.66 0.66 MWD_M 73 5194.05 62.05 309.12 100.00 3796.44 2590.96 1876.24 -2187.55 2881.95 310.62 0.87 MWD_M 74 5294.05 62.22 309.73 100.00 3843.18 2671.23 1932.38 -2255.84 2970.34 310.58 0.57 MWD_M 75 5394.05 62.06 309.90 100.00 3889.91 2751.24 1988.99 -23.23.75 3058.74 310.56 0.22 MWD_M 76 5494.05 62.55 309.63 100.00 3936.38 2831.42 .2045.62 -2391.81 3147.27 310.54 0.55 MWD_M 77 5594.05 62.33 308.03 100.00 3982.65 2912.29 2101.21 -2460.87 3235.88 310.49 1.44 MWD_M 78 5694.05 62.19 308.96 100.00 4029.20 2993.24 2156.30 -2530.14 3324.34 310.44 '0.83 MWD_M 79 5794.05 62.72 308.81 100.00 4075.44 3074.09 2211.96 -2599.16 3412.97 310.40 0.55 MWD_M 80 5894.05 63.43 308.19 100.00 4120.73 3155.63 2267.46 -2668.93 3502.08 310.35 0.90 MWD_M 81 5994.05 62.95 308.41 10Q. 00 4165.83 3237.39' 2322.78 -2738.97 3591.28 310.30 0.52 MWD_M 82 6094.05 62.97 308.85 100.00 4211.29 3318.77 2378.38 -2808.55 3680.31 310.26 0.39 MWD_M 83. 6194.05 62.49 308.65 100.00 4257.11 3399.91 2434.02 -2877.87 3769.16 310.22 0.51 MWD_M 84 6294.05 61.88 309.28 100.00 4303.77 3480.51 2489.63 -2946.64 3857.59 310.19 0.83 MWD_M 85 6394.05 61.40 308.97 100.00 4351.27 3560.60 2545.16 -3014.91 3945.57 310.17 0.55 MWD_M 86 6494.05 61.77 309.12 100.00 4398.86 3640.70 2600.56 -3083.22 4033.51 310.15 0.39 MWD_M 87 659~05 61.76 309.51 100.00 4446.17 3720.76 2656.38 -3151.38 4121.60 310.13 0.34 MWD_M 88 6694.05 61.84 307.95 100.00 4493.42 3801.22 2711.52 -3220.13 4209.70 310.10 1.38 MWD_M 89 6794.05 62.26 306.94 100.00 4540.30 3882.65 2765.23 -3290.26 4297.94 310.04 0.99 MWD_M 90 6894.05 62.46 307.90 100.00 4586.69 3964.33 2819.06 -3360.61 4386.44 309.99 0.87 MWD_M [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL sCHLUMBERGER Survey Report 21-Apr-2001 16:46:53 Seq Measured Incl Azimuth Course TVD Vertical # depth angle angle length depth section - (ft) (deg) (deg) (ft) (ft) (ft) 91 6973.44 62.91 306.84 79.39 4623.12 4029.40 92 7068.27 62.96 306.33 94.83 4'666.27 4107.73 93 7163.65 60.97 306.12 95.38 4711.09 4186.02 94 7258.58 60.97 307.18 94.93 4757.16 4262.97 95 7352.89 61.14 307.07 94.31 4802.81 4339.23 96 7446.67 60.63 307.26 93.78 4848.44 4414.92 97 7541.03 59.91 306.40 94.36 4895.23 4490.79 98 7636.26 61.03 306.71 95.23 4942.17 4567.67 99 7731.66 62.26 306.73 95.40 4987.47 4645.47 100 7826.59 62.23 307.40 94.93 .5031.68 4723.13 101 7918.42 61.90 308.42 91.83 5074.70 4797.66 102 8015.44 61.52 307.34 97.02 5120.69 4876.17 103 8109.06 62.21 307.68 93.62 5164.83 4952.24 104 8208.10 62.30 307.40 99.04 5210.94 5032.99 105 8302.25 62.12 306.87 94.15 5254.83 5109.95 106 8397.44 62.18 306.72 95.19 5299.30 107 8491.80 62.59 309.43 94.36 5343.05 108 8587.18 62.79 309.58 95.38 5386.81 109 8682.35 62.18 310.55 95.17 5430.78 110 8777.26 61.98 310.82 94.91 5475.22 111 8872.34 62.28 311.75 95.08 112 896.6.69 62~.48 310.45 94.35 113 9062'.41 63.07 310.76 95.72 114 9154.40 62.03 310.80 91.99 115 9250.07 62.49 310.41 95.67 5519.66 5563.41 5607.20 5649.60 5694.13 5737.49 5781.44 5826.36 5871.10 5917.96 116 9344.53 62.86 310.69 94.46 117 9438.97 61.68 311.25 94.44 118 9533.32 61.45 309.84 94.35 119 9626.51 61.17 309.25 93.19 120 9723.80 61.24 310.08 97.29 Page 5 of 9 Displ Displ Total At DLS Srvy Tool +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (deg) 100f) type type 2861.87 -3416.67 2912.20 -3484.48 2961.95 -3552.39 3011.49 -3618.98 3061.31 -3684.79 3110.80 -3750.08 3159.92 -3815.66 3209.27 -3882.22 3259.47 -3949.51 3310.10 -4016.54 3359.94 -4080.55 3412.40 -4147.98 3462.67 -4213.47 3516.08 -4282.97 3566.36 -4349.37 5187.91 .3616.77 -4416.77 5264.61 3668.33 -4482.58 5341.51 3722.24 -4547.97 5417.75 3776.57 -4612.56 5493.10 3831.24 -4676.16 5568.23 5643.08 5719.61 5792.90 5869.03 3886.69 -4739.31 3941.65 -4802.31 3997.04 -4866.93 4050.36 -4928.74 4105.47 -4993.03 5944.52 -6019.45 6094.08 6168.23 6245.49 4456.90 4541.20 4625.22 4708.09 4790.54 4872.39 4954.22 5036.96 5120.81 5204.75 5285.84 5371.24 5453.75 5541.36 5624.59 5708.67 5792.25 5877.00 5961.39 6045.23 6129.23 6212.79 6297.89 6379.50 6464.15 6548.05 6631.62 6714.57 6796.31 6881.57 309.95 309.89 309.82 309.77 309.72 309.68 309.63 309.58 309.53 309.49 309.47 309.44 309.41 309.38 309.35 309.31 309.30 309.30 309.31 309.33 309.36 309.38 309.40 309.41 309.43 309.44 309.46 309.48 309.48 309.48 4160.03 -5056.80 4214.83 -5119.91 4268.77 -5182.96 4320.81 -5245.99 4375.24 -5311.63 1.31 0.48 2.10 0.98 0.21 0.57 1.10 1.21 1.29 0.63 1.05 1.06 0.80 0.27 0.53 0.15 2.58 0.25 1.11 0.33 0.92 1.24 0.68 1.13 0.60 0.47 1.36 1.34 0.63 0.75 MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey 'Report 21-Apr-2001 16:46:53 Page 6 of 9 Seq MeaSured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 9818.07 62.17 309.19 94.27 122 9913.66 62.21 309.79 95.59 123 10006.65 62.74 309.75 92.99 124 10104.88 62.26 307.72 98.23 125 10199.83 62.35 307.96 94.95 126 10292.96 62.26 309.07 127 10387.42 62.31 308.12 128 10484.24 62.19 308.69 129 10576.31 61.94 308.75 130 10672.60 61.84 308.82 131 10767.28 61.56 307.60 132 10860.59 62.13 308.16 133 10926.64 62.38 308.55 134 11020.62 62.76 308.53 135 11113.79 62.15 309.77 136 11211.98 62.10 309.65 137 11305.99 62.35 309.76 138 11398.59 61.23 308.92 139 11494.12 61.52 308.96 140 11589.36 61.81 308.69 141 11683.37 62.25 308.65 142 11777.47 61.66 308.88 143. 1'1872.13 61.71 308.19 144 11969.22 61.56 309.69 145 12063.55 61.75 308.44 146 12156.69 61.67 308.02 147 12251.16 61.85 308.44 148 12345.94 62.44 306.97 149 12443.42 62.92 307.05 150 12532.49 62.06 308.06 93.~3 94.46 96.82 92.07 96.29 94.68 93.31 66.05 93.98 93.17 98.19 94.01 92.60 95.53 95.24 94.01 94.10 94.66 97.09 94.33 93.14 94.47 94.78 97.48 89.07 depth (ft) 5962.65 6007.25 6050.22 6095.58 6139.71 6183.00 6226.93 6272.01 6315.14 6360.51 6405.40 6449.43 6480.17 6523.47 6566.56 6612.46 6656.27 6700.04 6745.81 6791.01 6835.10 6879.35 6924.25 6970.37 7015.16 7059.30 7104.00 7148.29 7193.03 7234.17 Vertical section (ft) 6320.73 6397.46 6472.12 6551.66 6628.94 Displ Displ Total At DLS Srvy Tool +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (deg) i00f) type type 4428.18 -5375.55 4481.95 -5440.80 4534.70 -5504.18 4589.22 -5572.14 4640.79 -5638.54 6704.35 6780.77 6859.20 6933.47 7010.97 4692.14 -5703.06 4744.31 -5768.41 4797.54 -5835.56 4848.42 -5899.02 4901.62 -5965.23 7087.39 7162.98 7216.51 7292.78 7367.95 4953.18 -6030.73 5003.70 -6095.66 5039.97 -6141.50 5091.94 -6206.74 5144.09 -62.70.81 7446.57 .5199.55 -6337.58 7521.92 5252.69'-6401.57 7596.06 5304.42 -6464.68 7672.49 5357.12 -6529.90 7748.97 5409.67 -6595.21 7824.81 7900.61 7976.81 8054.67 8130.27 5461.55 -6660.03 5513.55 -6724.79 5565.47 -6789.98 5619.16 -6856.42 5671.48 -6920.88 ~8205.44 8281.71 8358.81 8438.91 8511.68 5722.23 -6985.31 5773.73 -7050.68 5824.98 -7116.98 5877.11 -7186.14 5925.26 -7248.77 6964.58 7049.13 7131.59 7218.71 7302.74 309.48 309.48 309.48 309.47 309.46 7385.19 7468.80 7554.47 7635.81 7720.74 309.45 309.44 309.42' 309.42 309.41 7804.08 7886.32 7944.77 8028.17 8110.78 309.40 309.38 309.37 309.37 309.36 8197.57 8280.75 8362.35 8446.20 8530.03 309.37 309.37 309.37 309.37 309.36 8613.05 8696.09 8779.42 8864.85 8947.86 309.35 309.35 309.34 309.34 309.33 9029.86 9113.07 9196.84 9283.37 9362.33 309.32 309.31 309.30 309.28 309.26 1.29 MWD_M 0.56 MWD_M 0.57 MWD_M 1.90 MWD_M 0.24 MWD_M 1.06 MWD_M 0.89 MWD_M 0.54 ' MWD_M 0.28 MWD_M 0.12 MWD_M 1.17 MWD_M 0.81 MWD_M 0.65 MWD_M 0.40 MWD_M 1.35 MWD_M 0.12 MWD_M 0.29 MWD_M 1.45 MWD_M 0.31 MWD_M 0.39 MWD_M 0.47 MWD_M 0.66 MWD_M 0.64 MWD_M 1.37 MWD_M 1.18 MWD_M 0.41 MWD_M 0.44 MWD_M 1.51 MWD_M 0.50 MWD_M 1.39 MWD_M [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 21-Apr-2001 16:46:53 Page 7 of 9 Seq Measured Incl Azimuth Course TVD Vertical Displ Disp1 Total ~ depth angle angle length 'depth section +N/S- +E/W- displ - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) 151 12630.95 59.70 311.83 98.46 7282.10 8589.43 5980.44 -7314.71 9448.32 309.27 4.11 MWD_M 152 12721.19 59.20 313.10' 90.24 7327.97 8658.17 6032.91 -7372.04 9525.91 309.30 1.33 MWD_M 153 12731.00 59.29 313.20 9.81 7332.98 8665.57 6038.67 -7378.19 9534.32 309.30 1.27 MWD 154 12747.00 59.45 311.00 16.00 7341.14 8677.79 6047.90 -7388.40 9548.07 309.30 11.87 MWD 155 12765.55 59.54 310.86 18.55 7350.55 8692.12 6058.37 -7400.48 9564.04 309.31 0.81 MWD ~-~ 156 12861.28' 66.42 310.16 95.73 7394 02 8768.82 6113.72 -7465.29 9649.25 309.32 7.22 MWD 157 12958.45 72.79 311.39 97.17 7427.86 8850.54 6173.19 -7534.21 9740.25 309.33 6.66 MWD_M 158 13055.92 74.92 312.08 97.47 7454.97 8933.89 6235.51 -7604.07 9~33.79 309.35 2.29 MWD_M 159 13144.97 75.15 312.21 89.05 7477.96 9010.21 6293.24 -7667.85 9919.72 309.38 0.29 MWD_M 160 13244.22 75.32 311.95 99.25 7503.25 9095.39 6357.56 -7739.09 10015.59 309.40 0.31 MWD_M At. DLS Srvy Tool Azim (deg/ tool qual (deg) 100f) type type 161 13341.26 76.05 311.82 97.04 7527.25 9178.99 6420.33 -7809.09 10109.53 309.43 0.76 MWD_M 162 13435.69 76.66 312.73 94.43 7549.52 9260.29 6482.06 -7876.99 10201.18 309.45 1.14 MWD_M 163 13532.18 76.45 312.26 96.49 7571.96 9343.27 6545.46 -7946.18 10294.'89 309.48 0.52 MWD_M 164 13599.86 76.27 314.46 67.68 7587.92 9400.96 6590.61 -7994.00 10360.51 309.50 3.17 MWD_M 165 13695.75 76.25 312.70 95.89 7610.70 9482.47 6654.82 -80.61.47 10453.42 309.54 1.78 MWD_M 166 13790.89 76.07 312.61 95.14 7633.46 9564 04 6717.41 -8129.41 10545.66 309.57 0.21 MWD_M 167 13886.95 75.96 311.40 96.06 7656.67 9646.82 6779.79 -8198.67 10638.79 309.59 1.23 MWD_M 168 13983.80 76.72 309.70 96.85 7679.55 9731.48 6840.97 -8270.18 10732.88 309.60 1.88 MWD_M 169 14077.74 77.80 308.34 93.94 7700.26 .9814.94 6898.65 -8341.37 10824.50 309.59 1.82 MWD_M 170 14177.14 78.96 306.57 99.40 7720.29 9904.69 6957.85 -8418.65 10921.79 309.57 2.10 MWD_M 171 14272.70 79.25 303.51 95.56 7738.35 9992.63 7011.72 -8495.47 11015.32 309.53 3.16 MWD_M 172 14364.'35 79.43 301.41 91.65 7755.31 .10078.38 7060.06 -8571.47 11104.71 309.48 2.26 MWD_M 173. 14460.66 78.53 299.17 96.31 7773.72 10169.41 7107.74 -8653.09 11198.03 309.40 2.47 MWD_M 174 14558.39 77.86 296.95 97.73 7793.71 10262.45 7152.74 -8737.50 11291.83 309.30 2.33 MWD_M 175 14653.85 76.95 293.77 95.46 7814.54 10353.98 7192.64 -8821.67 11382.26 309.19 3.39 MWD_M 176 14746.41 76.07 290.10 92.56 7836.13 10443.24 7226.26 -89'05.14 11468.23 309.06 3.97 MWD_M 177 14844.39 ,75.10 286.76 97.98 7860.53 10537.91 7256.26 -8995.15 11557.08 308.89 3.45 MWD_M 178 14941.30 74.15 282.61 96.91 7886.24 10631.33 7279.95 -9085.52 11642.35 308.70 4.24 MWD_M 179 15036.29 73.56 279.31 94.99 7912.66 10722.37 7297.30 -9175.08 11723.17 308.50 3.39 MWD_M 180 15131.32 72.85 275.93 95.03 7940.12 10812.65 7309.36 -9265.24 11801.33 308.27 3.49 MWD_M [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 21-Apr-2001 16:46:53 Page 8 of 9 Seq Measured Incl Azimuth Course TVD # depth angle angle length dep. th - (ft) (dog) (dog) (ft) (ft) vertical Displ section +N/S- (ft) (ft) Displ Total At' DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) i00f) type type 181 15226.69 71.92 272.53 95.37 7968.99 10902.03 7316.07 -9355.87 11876.75 308.02 3.53 MWD_M 182 15323.06 71.07 268.66 96.37 7999.59 10990.67 7317.03 -9447.23 11949.44 307.76 3.91 MWD_M 183 15419.13 70.47 266.07 96.07 8031.23 11077.27 7312.86 -9537.83 12018.66 307.48 2.62 MWD_M 184 15513.72 70.38 264.93 94.59 8062.93 11161.46 7305.87 -9626.68 12085.06 307.20 1.14 MWD_M 185 15608.14 70.19 266.25 94.42 8094.78 11245.47 7299.04 -9715.30 12151.67 306.92 1.33 MWD_M 186 15704.76 69.25 265.74 96.'62 8128.27 11331.34 7292.71 -9805.71 12220.29 306.64 1.09 MWD_M 187 15801.03 68.28 266.03 96.27 8163.14 11416.30 7286.27 -9895.21 12288.41 306.37 1.05 MWD_M 188 15896.36 67.32 266.35 95.33 8199.16 11500.02 7280.40 -9983.28 12355.97 306.10 1.05 MWD_M 189 '15993.38 65.92 265.68 97.02 8237.66 11584.40 7274.22 -10072.11 12424.24 305.84 1.58 MWD_M 190 16089.00 64.79 265.18 95.62 8277.53 11666.47 7267.29 -10158.75 1249.0.54 305.58 1.27 MWD_M 191 16185.88 63.21 266.04 96.88 8320.00 11748.77 7260.63 -10245.56 12557.40 305.32 1.82 MWD_M 192 16284.06 61.73 266.79 98.18 8365.38 11831.46 7255.18 -10332.45 12625.26 305.08 1.65 MWD_M 193 16377.12 60.39 266.75 93.06 8410.41 11908.97 7250.59 -10413.76 12689.26 304.85 1.44 MWD_M 194 16473.09 59.89 266.23 95.97 8458.19 11988.05 7245.49 -10496.83 12754.63 304.62 0.70 MWD_M 195 16566.80 59.53 266.98 93.71 8505.45 12064.98 7240.70 -10'577.60 12818.48 304.39 0.79 MWD_M 196 16664.07 59.13 267.97 97.27 8555.07 12144.91 7237.01 -10661.18 12885.47 304.17 0.97 MWD_M 197 16757.04 58.33 269.45 92.97 8603.33 12221.32 7235.22 -10740.62 12950.27 303.97 1.61 MWD_M 198 16853.32 58.28 271.54 96.28~ 8653.92 12300.74 7235.93 -10822.54 13018.68 303.77 1.85 MWD_M 199 16952.03 59.87 274.98 98.71 8704.66 12383.74 7240.76 -10907.05 13091.69 303.58 3.40 MWD_M 200 17051.07 59.90 275.56 99.04 8754.35 12468.26 7248.63 -10992.36 13167.18 303.40 0.50 MWD_M 201 17145.35 61.33 276.92 94.28 8800.61 12549.52 7257.55 -11074.02 13240.32 303.24 1.98 MWD_M 202 17235.49 64.48 275.78 90.14 8841.66 12628.92 7266.42 -11153.77 13311.92 303.08 3.67 MWD_M 203 17332.87 65.87 274.06 97.38 8882.55 12716.02 7273.99 -11241.81 13389.90 302.90 2.15 MWD_M 204 17429.82 63.69 273.49 96.95 8923.86 12802.15 7279.77 -11329.33 13466.58 302.72 2.31 MWD_M 205 17517.63 6~.88 273.80 87.81 8964.01 12878.80 7284.73 -11407.26 13534.87 302.56 2.09 MWD_M 206 17620.81 59.69 273.47 103.18 9014.37 12967.19 7290.44 -11497.12 13613.76 302.38 2.14 MWD_M 207 17716.82 57.90 273.63 96.01 9064.11 13047.77 7295.52 -11579.08 13685.75 302.21 1.87 MWD_M 208 17811.60 56.16 273.58 94.78 9115.69 13125.81 7300.52 -11658.44 13755.61 302.05 1.84 MWD_M 209 17908.83 54.05 272.44 97.23 9171.31 13203.91 7304.72 -11738.07 13825.38 301.89 2.37 MWD_M 210 18004.74 51.47 271.69 95.91 9229.35 13278.43 7307.48 -11814.37 13891.67 301.74 2.76 MWD_M [(c)2001 Anadrill IDEAL ID6_IC_08] ANADRILL SCHLUMBERGER Survey'Report 21-Apr-2001 16:46:53 Page 9 of 9 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ depth section +N/S- (ft) (ft) (ft) Displ Total At- DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type 211 18100.68 48.83 271.31 95.94 9290.82 13350.15 7309.41 -11887.99 13955.35 301.59 2.77 MWD_M 212 18196.33 46.55 270.48 95.65 9355.20, 13418.85 7310.53 -11958.71 14016.23 301.44 2.47 MWD_M 213 18291.56 44.24 269.50 95.23 9422.07 13484.44 7310.53 -12026.50 14074.11 301.29 2.53 MWD~ 214 18388.32 41.24 269.02 96.76 9493.13 13547.75 7309.69 -12092.16 14129.82 301.15 3.12 MWD_M 215 18439.03 39.82 268.88 50.71 9531.67 13579.47 7309.08 -12125.11 14157.72 301.08 2.81 MWD_M -~-~Final Projected Survey: 216 18512.00 37.80 269.36 72.97 9588.52 13623.53 7308.38 -12170.83 14196.53 300.98 2.80 Projected [(c)2001 Anadrill IDEAL ID6_1C_08] bp ( ('" Date: 05-10-2001 Transmittal Number:92098 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type NK-O7A 04-21-2001 SCH - 0 18439.03 SURVEY REPORT (HARDCOPY;) NK-O7A 04-21-2001 SCH - 0 18439.03 SURVEY REPORT (DISKETTE;) P~ign a~nd Return onetcopy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center RECEIVED MAY 14- 2001 ,:Uaska 0il & Gas Oons. Oommissior. Anchorage Phillips Alaska, Attn: Sandy Lemke Exxon Mobil, Attn: Susan Nisbet AOGCC, Attn Lisa Weepie Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 AI,ASKA OIL AND GAS CONSERVATION C0P~ISSION TONY KNOWLES, GOVERNOR 333 W. 7'r" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage Alaska 99519-6612 Re: Niakuk NK-07A BP Exploration (Alaska) Inc. Permit No: 201-063 Sur Loc: 1250' NSL, 1125' WEL, SEC. 36, T12N, R15E, UM Btmhole Loc. 3327' NSL, 3087' WEL, SEC. 27, T12N, R15E Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above referenced Well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other.required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling neW hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~Sincerely' / ~ ,q T. Se0m/ount, Jr. Commissi~er BY ORDER OF THE COMMISSION · DATED this ~ '~'( day of April, 2001 jjc/Enclosures cc: Department offish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA " ALASI~{_. OIL AND GAS CONSERVATION CO~,,.,SSION PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Ddll [] Redrill lb. Type of well [] Service [] Development Gas [] Single Zone [] Re-Entry [] Deepen [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned RKB = 52.7' Niakuk Oil Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034629 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1250' NSL, 1125' WEL, SEC. 36, T12N, R15E, UM Niakuk At top of productive interval 8. Well Number 3186' NSL, 2023' WEL, SEC. 27, T12N, R15E NK-07A Number 2S100302630-277 At total depth 9. Approximate spud date 3327' NSL, 3087' WEL, SEC. 27, T12N, R15E 04/12/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034626, 1952' MDI No Close Approach 2560 18790' MD / 9630' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 12780' MD Maximum Hole Angle 76 ° Maximum surface 3555 psig, At total depth (TVD) 8949' / 4450 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stare data) 8-1/2" 4-1/2" 12.6# L-80 Hydril 521 6160' 12630' 7281' 18790' 9630' 936 sxClass'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 15694 feet Plugs (measured) true vertical 9676 feet Effective depth: measured 15614 feet Junk (measured) 3-3/8" x 30' perf gun w/overshot. Top at approx. 15538'. true vertical 9603 feet (09/94) Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Arcticset (Approx.) 80' 80' Surface 5897' 13-3/8" 1943 sx PF 'E' 375 sx Class 'G' 5937' 4143' Intermediate 14927' 9-5/8" 380 sx Class 'G' 14965' 9010' Production Liner 903' 7" 200 sx Class 'G' 14791' - 15694' 8850' - 9676' RECEIVED Perforation depth: measured 15126'-15186', 15206'-15216', 15216'-15241', 15256'-15266' ~t~AF{2_ 8 2007 true vertical 9159' -09214', 9232' - 9241'. 9241' - 9264', 9278' - 9287' ,~la~k,a 0JJ & (,la~ C~"~,~;. 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Bill Isaacson, 564-5521 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Senior Drilling Engineer Date 3/~.') Signed Dan Stone ~,,,-., . "~.,~.. ~ Permit Number I AP, Number I , pprova, Date I See cover'etter .2.c:>/- ~2, ~'~ 50- 02922410-01 t~. ~,.~ { for other requirements -cond,t,ons of Approval: Samples Required [] Yes ,,~No Mud Log Required [] Yes Hydrogen Sulfide Measures x~l~'Yes [] No,,,Directi°nal Survey Required ~Yes [] No Required Working Pressure for BOPE [] 2K [] 3K I~i~[~K [] 5K [] 10K [] 15K [] 3.5K psi for CTU by order of ~ / _.Approved By~,/J/' ,~ ,/,'/' ~ //~'~, r'~, ~ ~"'~ ~ ~ ~C~mmissioner the commission Date Form10-401 Rev. 12-01-85 / 0ifx!/'-\L Submit ln Triplicate I Well Name: I NK-07A Drill and Complete Summary I Type of Redrill (producer or injector): I Producer Surface Location: x = 721,440.24 / Y =5,979,782.16 1250' FSL 1124' FEL S36 T12N R15E Umiat Target Location: x = 709,772.00 / Y = 5,986,665.00 3186' FSL 2023' FEL S27 T12N R15E Umiat Bottom Hole Location: X = 708,705.00 / Y = 5,986,776.07 3327' FSL 3087' FEL S27 T12N R15E Umiat I AFE Number: 15L1503 I I Estimated Start Date: 104/12/01 IUD: I~ 8,790' I I TVD: 19630' Rig: I Doyon 14 I Operating days to complete: 125.0 I Cellar Elevation'119.2' I RKB: 52.7' I Well Design (conventional, slimhole, etc.): I Conventional Big Bore - 9-5/8" Sidetrack I Objective:I Niakuk Kuparuk Development MAR 2 8 2001 Formation Markers ,41aska Oi! & ~as Formation Tops MD TVDss Comments ~Chorage Base Permafrost SV3 SV1 Ugnu 4A West Sak 6500' Kick-off Point 12,780' 7305' Kick-off in lower-most West Sak Sands CM3 / K-12 13,042' 7410' Tuffs 16,348' 8350' Top HRZ 17,248' 8800' Top Kuparuk 17,546' 8949' Est. pore pressure 4400 psi (9.4 ppg EMW at Top Kuparuk at 9002' TVD) TD 18,790' 9577' TD with-in Kuparuk Zone lA Top Kingak Not Reached TD Criteria: 180' MD below bottom expected perforation to provide -90 to 100' of cased hole rat-hole. 'Ssior Casing/Tubing Program Hole ~ize Csg/ ' Wt/Ft Grade Conn Length Top Btm Tb~l O.D. MDfrVD MDfrVD 8-1/2" 4-1/2" 12.6# L-80 Hydril 521 -6160' 12,630'/7281' 18,790'/9630" Tubing 4-1/2" 12.6# L-80 IBT-M -12,710' GL 12,740' / 7338' NK-07A Permit to Drill 3/26/01 Page 1 Directional KOP: I 12,780' MD Maximum Hole Angle: Close Approach Well: Survey Program: -76° In Interval from 13,073' to 15,200' MD -60° Through Reservoir Target Interval All wells pass BP Close Approach guidelines. The nearest close approach well is NK-27 which is -296' well-to-well at 15,593' MD and passes under Major Risk rules. Standard MWD Surveys from kick-off to TD. Mud Program 8-1/2" Pro(Juction Hole I LSND (12,780' to 18,790' MD) I Interval Density PV YP Tauo pH HTH P (ppg) (cp) (Ib/100ft2) (Ib/100ft2) (cc's) Milling 9.4 9-12 25-35 3-8 Colville 9.4 - 9.6 10-15 20-25 4-7 8.5 - 9.5 Tuffs 9.6 10-15 20-25 4-7 8.5 - 9.5 (increasing to 10.9) HRZ 10.9 12-18 20-25 4-7 8.5 -9.5 < 9 Kuparuk 10.9 12-18 20-25 4-7 8.5 -9.5 < 9 Logging Program 8 1/2"-Int~rmedia-te / Production: Drilling: FIRST BIT RUN WITH MILL-TOOTH MWD / GR - Realtime on first bit trip SECOND BIT RUN WITH ROTARY STEERABLE AND PDC BIT MWD/GR/Res / PWD - Realtime over entire interval after trip for PDC. Den / Neu - Recorded over entire interval after trip for PDC. Sample catchers through the Kuparuk interval only. Open Hole: No open hole logs are planned. Cased Hole: No cased hole logs are planned. Cement Pro lram I Casing Size !4-1/2" Production Liner I I Basis: Lead: None Tail: Based on 2944' of open hole with 30% excess and 82' of 4-1/2" shoe joint. Tail TOC: -15,850' MD (8210' TVD).- approximately 1700' MD above top Kuparuk. IFluid Sequence & Volumes: Pre 70 bbls Chemical wash at 8.3 ppg Flush Spacer 30 bbls MudPUSH Viscosified Spacer weighted to 12.0 ppg Lead None Tail 195 bbl / 1095 ft3 / 936 sks of Dowell Premium Latex 'G' at 15.8 R E[ E IV E D ppg and1.17 cf/sk, BHST194°/ BHCT140°, TT=4.5to5hrs *See Attached Dowell Cement Program for Details on Cement Formulation* MAR 28 200 Page 2 Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4000 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- · Maximum anticipated BHP: 4450 psi @ 8949' TVDss - Kuparuk · Maximum surface pressure: 3555 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/fi) · Planned BOP test pressure: 4000 psi · Planned completion fluid: 9.8 ppg Brine / 6.8 ppg Diesel Disposal ° No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. mAR 28 2001 41aska 011 & Cas C0r~s NK-07A Permit to Drill 3/26/01 Page 3 Sidetrack and Complete Procedure Summary Pre-Rig Work: 1. RU slickline, drift tubing and tag PBTD. Dummy off all GLM's. Test the integrity of the dummied off tubing string by applying -2000 psi on the annulus. COMPLETE (2/24-27/01): All GLMs dummied off and tubing tested to 2000 psi. 2. RIH with CTU and perform a cement P&A using 15.8 ppg class 'G' cement. Use adequate cement volume to fill the 7" liner from PBTD at 15,614' MD and extend the cement plug up into the tubing tail approximately 100', plus squeeze 5 bbls to the perforations. COMPLETE (2/27/01): Coil laid-in cement P&A plug up to -13,700'. 3. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut. COMPLETE (3~2- 4/01): Slick-line tagged high at -9351' MD and recovered bailer full of green cement. Had to RU CTU and perform clean-out. Coil ran 3.75" mill to -13,500' MD with only minor resistance. Slickline then successfully drifted tubing to -13,500' MD. 4. Test the integrity of the cement plug and 9-5/8" casing by simultaneously pressure testing both the tubing and 9-5/8" annulus to 3000 psi for 30 minutes. COMPLETE (3/2/01): Tubing tested to 2500 psi, annulus to 3500 psi. 5. RU E-line. Cut the 4 Y2" L-80 tubing at approximately 13,350' MD. COMPLETE (3/7/01): Cut at 13,364' MD. 6. Displace the well to clean seawater by circulating down tubing through the tubing cut. Freeze protect top 2200' MD with diesel. COMPLETE (3/06/01): Well displaced to KCI water and freeze protected. 7. Test the FMC 9-5/8" packoff to 3800 psi (80% of 9-5/8" 47# L-80 collapse) and tubing hanger seals to 5000 psi for 30 minutes. COMPLETE (2/22/01): Packoff passed test to 3000 psi (lost 0 psi in 30 min), Tubing hanger passed test to 5000 psi (lost 160 psi in 30 min). 8. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Remove the well house and flowlines. If necessary, level the pad. Ri.q 1. 2. 3. 4. 5. 6. Operations: MIRU Doyon 14. Circulate out freeze protection and displace well to seawater. Set TWC & test from below. Nipple down tree. Nipple up and test BOPE to 250 / 3500 psi. Pull and lay down 4-1/2" tubing from E-line cut and above. MU 9-5/8" window milling assembly and RIH with 5" DP to top of tubing stub. Circulate well clean. POOH. RU E-line and set CIBP to place top of whipstock at -12,780' MD, which is in a clean sandstone at the base of the West Sak. Test the 9-5/8" casing to 3500 psi for 30 minutes. 7. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on BP. Mill window in 9-5/8" casing. Perform FIT test to 12.8 ppg EMW. POOH. 8. MU 8-1/2" drilling assembly with conventional mud motor and milltooth bit (run MWD/GR only). RIH to whipstock. Kick-off and drill the build & turn section to get the well lined out for the Upcoming rotary steerable run. The build & turn section is planned for -265' of 6°/100'. POOH. 9. MU 8-1/2" rotary steerable assembly and RIH. Drill ahead as per directional plan to TD at +/-18,790' MD (9630' TVD). Condition hole for running liner, spot liner running pill, and POOH. 10. Run and cement a 4 Y2", 12.6# production liner. Displace cement with drilling mud. Release from liner and circulate hole clean. Test wellbore to 2000 psi to verify liner top packer is set. POOH. 11. PU 3-3/4" clean-out assembly on 2-7/8" x 5" drillstring. RIH to PBTD and test the 9~5/8" casing and 4-1/2" liner to 3500 psi for 30 minutes. Displace well to 9.8 ppg brine and spot perf pill. POH. 12. RIH with DP conveyed perf guns (-400' of 2 W' guns) on 2-7/8" x 5" drillstring. Tie-in w/e-line and place guns on depth. Set packer and circulate in diesel'for desired underbalance. Fire guns, circulate BU, and POOH. 13. Run 4-1/2", 12.6# L-80 gas lift completion. The production packer will be set in the 7" casing which is run at the 4-1/2" liner top. Tag the 7" x 4-1/2" crossover and space-out the packer -1 to 2' above the crossover. 14. Drop ball/rod & set packer. Test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 15. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 16. Freeze protect the well to -100' below the top GLM and secure the well. 17. Rig down and move off. Post-Ric~ Work: 1. Pull the ball and rod / RHC plug from below the production packer. Install gas lift MAR 2 8 2001 NK-O7A Permit to Drill 3/26/01 Alaska Oil & Gas ¢l~tr~ ¢JornmJssJor Anchorage Job 1: MIRU Hazards and Contingencies > Two wells will need to be shut-in for the NK-07A rig move. Well NK-27 and NK-28 are located 20' and 15' from NK-07 respectively. The wells will need to be shut-in at the surface and the SSSV. All surface flowlines and gas lift lines will be depressured to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. > Heald Point Niakuk Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: NK-07 39 ppm Apr 02, 1998 (well was shut-in 4thQ 1998) Adjacent producers at Surface: NK-27 25 ppm Oct 13, 00 NK-08 44 ppm Jun 13, 99 (well was shut-in August of 1999) NK-28 35 ppmApr 25, 00 NK-29 20 ppm Oct 14, 00 Adjacent producers at TD: All as above: NK-07, 08, 27 NK-34 30 ppm Oct 3, 00 The maximum recorded level of H2S on the pad was 60 ppm from NK-28 on Jan 17, 2000. Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. Job 2: Decomplete Well Hazards and Contingencies Y NORM test all retrieved well head and completion equipment. RECEIVED Job 3: Run Whipstock Alaska Oil & (~as Cons. C0mmissio~. Hazards and Contingencies .Anchorage > Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. Job 7: Drillinq Intermediate/Production Hole Hazards and Contingencies No fault crossings are planned in the drilling of NK-07A. As planned, the well bore will drill parallel to the large east/west-trending Niakuk fault with approximately 500 to 600' of separation at the Top Kuparuk Location and at TD. This fault will be south of the wellbore when entering the Kuparuk target and the target polygon should be adequately sized to assure this fault is avoided. Cuttings gas and gas cut mud has been encountered within the West Sak interval at Niakuk. This interval does not contain substantial amounts of hydrocarbons and will not require cement isolation. The most recent Niakuk drilling history has shown this interval to be drilled with mud weights ranging from 9.1 to 9.3 ppg without any problems, nevertheless monitor for any signs of overpressure. ~> The NK-07A well path will drill full sections of the Tuffs and HRZ shales. Both formations have been troublesome in the Niakuk area and have shown severe hole instability problems. Follow all shale drilling practices to limit high ECD's. We will also be using increased mud weights and shale stabilizers in the drilling fluid. ~ The Kuparuk reservoir pressure is expected to be 4400 psi (9.4 ppg EMW) at the NK-07A bottom hole location. Because of the high mud weights required to drill the surrounding shale intervals, we will be drilling this interval with mud weights up to 10.9 ppg (-700 psi overbalance to Kuparuk). Based upon offset drilling data, losses are not expected, however monitor the well closely while drilling this interval and NK-O7A Permit to Drill 3/26/01 Page 5 be prepared for potential losses by having fiberous LCM products on location. NK-62 encountered pressures as Iow as 3000 psi (RFT data) within the Kuparuk interval, and the well was successfully drilled without losses with mud weights of 10.6 ppg. Differential sticking will be a problem if the drill string or casing is left stationary for an extended period of time across the permeable West Sak or Kuparuk Sands. The kick tolerance for the 8Y2" open hole section would be an infinite influx assuming a kick from the Kuparuk at -17,546' MD. This is a worst case scenario based on an 9.5 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the 9-5/8" window, and 10.9 ppg mud in the hole. Drilling Close Approach: All wells pass BP Close Approach guidelines. The nearest close approach well is NK-27 which is -296' well-to-well at 15,593' MD and passes under Major Risk rules. Note tolerance lines and allowable deviation from planned NK-07A well-path. Job 9: Install 41/2" Production Liner Hazards and Contingencies ~ Long shale intervals will be exposed while running the liner. downward progress is not possible. Rotation of the liner may be necessary if Differential sticking could be a problem in the Kuparuk. The 10.9 ppg required for well bore stability of the HRZ will be -700 psi over balanced to the Kuparuk formation. Minimize the time the pipe is left stationary while running the liner. Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Job 11: Liner Clean-out Hazards and Contingencies ~ No hazards identified for this section of the well. RECEIVED MAR 28 2001 Alaska 0il & Gas Cons. O0mm~sm Job 10: DPC perforate Anchorage Hazards and Contingencies ~ At 9.8 ppg, the perforating/completion fluid will provide ~190 psi overbalance to the estimated Kuparuk pressure of 4400 psi. This pressure estimate is +/-100 psi, therefore, monitor the well closely after perforating for any signs of inadequate overbalance. Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Job 13: ND/NU/Release Ri_q Hazards and Contingencies ~ See Job 1 for adjacent well spacing. These are close well centers. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. NK-07A Permit to Drill 3/26/01 Page 6 TREE: 4" CIW WELLHEAD: FMC 13-5/8" UNIVERSAL BIG BORE. ACTUATOR:BAKER 13-3/8", 68 &72 #/ft, I L-80, NSCC 5937' 4-1/2", 12.6#/ft, NT-80, TUBING TUBING ID: 3.958" CAPACITY: .01522 BBL/FT Tubing Cut at -13,364' MD Top Cement P&A Plug at -13,700' MD TOP OF 14791' 7" LINER 9-5/8", 47#/ft, I 14965' I NT-80,NSCC PERFORATION SUMMARY Ref. Log: BHCS 6/23/94 SIZE .~PF INTERVAL :3PEN/SQZ'D 3-3/8" 6 15126-15186' MD P&A 3-3/8" 6 15206-15241' MD P&A 3-3/8" 6 15206-15241' MD P&A 3-3/8" 6 15256-15266' MD P&A 7", 29 #/ft, NT-80,NSCC PBTD I 15614' 15694' J KB. ELEV = 60.10 GL. ELEV: 19.20 TRSV LANDING NIPPLE ( SERIES 10 )(3.813" ID) 2209' 4.5" GAS LIFT MANDRELS (OTIS LB W/1.5" RA LATCH' 3512' 7779' 11512' 13519' 14376' 14612' TVDss. 2949' 4953' 6697' 7728' 8411' 8625' DEV .61° 62° 62° 45° 27° 24° NO. "X" NIPPLE ( OTIS ) ( 3.813" ID) 9-5/8" TIW PACKER (HBBP)(3.87"ID) "X" NIPPLE ( OTIS ) ( 3.813" ID) "XN" NIPPLE (OTIS) (3.725" ID) WLEG Status (6/1/95) Dummy Dummy Dummy Dummy Dummy Dummy Ptro ELMD Pso Orif I14682' 14743' 14778' 14795' 14816' 14819 15069 MARKER JOINT NOTE: 9-5/8" CASlJ~G.SET ON 1 ,,e e 200 Fish: 3-3/8 x 30 long pe~~er~hot planted. Top at 15,538' WL~~t~i,~siO telex dated 9-10-94. By: Cledwyn Hughes DATE REV. BY COMMENTS 6-30-94 M. LINDER ORIGINAL COMPLETION POOL7 9-20-94 JDB E-Line MD Marker Jr. 9-21-94 M.~'Linder Revised Perf's and Fish 3-26-01 WSI Actual Pre-Rig Work NIAKUK WELL: NK-07 APl NO:50-029-22410 i BP Exploration (Alaska) I TREE: 4-1/16" - 5M CIW WELLHEAD: 13 5/8" - 5M FMC NK-07A Proposed Completion Cellar Box Elevation = 19.2' Doyon 14 RKB = 52.7' 13-3/8", 68 &72 #/ft, L-80, NSCC 4-1/2" Halliburton 'Series 10' tubing retrievable SSSV w/control line to surface. I 2050' 4-1/2" Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS # TVD i Size Valve Type 1 TBD DV 2 TBD RP Shear 4 TBD DV TBD DV BAKER 7" x 9-5/8" +/-12,630' I Liner Tie Back Sleeve ZXP Liner Top Packer 'Flex Lock' Hydraulic Liner Hanger 2 joints 7" Hydri1511 Crossover to 4-1/2" Hydri1521 4-1/2" 12.6# L-80, IBT Tubing 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. 4-1/2" WireLine Entry Guide spaced-out immediately above 7" x 4-1/2" XO in liner. Window Milled from Whipstock Top of Window at +/-12,780' MD Bridge Plug set at +/-12,800' MD Pre-Rig Tubing Cut at +/-13,364' RECEIVED ~/AR 2 8 2001 Alaska 0ii & Gas Cons. CommJssjor~ Anchorage Top cement P&A plug at -13,700' MD 7" LinerTop 9-5/8", 47 #/ft, N80, NSOC J 14,965' i Plug Back Depth I +/-18t705' J 4-1/2", 12.6 #/ft, L-80, Hydril 521 J +/-18,790' J Perforations from 15,126' to 15,266' 7", 29 #iff, NT-80, NSCC J l 5,694'I Date Rev By Comments 3/26/01 WSI Proposed Completion NIAKUK WELL: NK-07A APl NO' 50-029-22410-01 Shared Services Drilling ii Report Date: Client: Field: Structure / Slot: Well: Borehole: UWIIAPI#: Survey Name I Date: Tort I AHD / DDI I ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid NIE Y/X: Grid Convergence Angle: Grid Scale Factor: Station ID Tie-In Survey Top of Window Base Whipstock KOP Crv 6/100 CM3 End Crv Crv 2.5/100 MDI 12721.24 12780.00 12796.00 12808.00 12900.00 13000.00 13041.85 13072.97 13728.14 13800.00 13900.00 14000.00 14100.00 14200.00 14300.00 NK-07A (P7) report.xls NK-07A Proposed Well Profile - Geodetic Report Alaska Drilling & Wells Niakuk Main Pad / NK-07 m "~ NK-o,ANK-O' F{~~lbl~l 50-029-22410-01 NK-07A (PT) / March 22, 2001 246.202° / 15095.82 fl / 6.860 / 1.56~ NAD27 Alaska State Planes, Zone 04, US Feel N 70.34705584, W 148.20223738 N 5979782.160 flUS, E 721440.240 flUS +1.69310068° 0.99995570 Schlumberger Survey I BLS Computation Method: Vertical Section Azimuth: O~y Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: Minimum Curvature / Lubinski 284.520° N 0.000 fl, E 0.000 fl KB 52.7 ft relative to Mean Sea Level 26.997° 57506.821 nT 80.872" April 15, 2001 BGGM 2000 True Nodh +26.997° Well Head Incl 59.20 59.74 60.09 60.09 65.59 313.10 7328.02 8649.13 6032.93 313.82 7357.87 8693.42 6067.75 311.64 7365.89 8705.62 6077.14 311.64 7371.87 8714.88 6084.05 312.13 7413.85 8787.54 6138.69 EI-W -7372.03 -7408.76 -7418.93 -7426.71 -7487.62 DLS I°/loof~) 0.00 1.40 12.00 0.00 6.00 Grid Coordinates Northing I"usl I 5985594.37 5985628.09 5985637.18 5985643.85 5985696.67 Easting 713893.53 713855.79 713845.35 713837.37 713774.87 GeographicCoordinates Latitude I Longitude N 70.36352739 W148.26212172 N 70.36362242 W148.26242037 N 70.36364804 W148.26250306 N 70.36366690 W148.26256631 N 70.36381601 W148.26306154 71.58 312.62 7450.35 8869.81 6201.41 -7556.36 74.08 312.81 7462.70 8905.05 6228.53 -7585.73 75.94 312.95 7470.75 8931.50 6248.99 -7607.76 75.94 312.95 7629.88 9490.39 6682.04 -8072.93 75.80 311.11 7647.43 9552.19 6728.70 -8124.69 6.00 6.00 6.00 0.00 2.50 5985757.33 5985783.57 5985803.37 5986222.46 5986267.57 713704.31 713674.15 713651.53 713173.79 713120.68 N 70.36398716 W148.26362045 N 70.36406117 W148.26385926 N 70.36411701 W148.26403838 N 70.36529873 W148.26782095 N 70.36542605 W148.26824185 75.63 75.48 75.36 75.27 75.21 308.53 7672.11 9639.80 6790.75 -8199.11 305.95 7697.07 9729.11 6849.35 -8276.19 303.37 7722.25 9819.96 6904.39 -8355.79 300.79 7747.60 9912.17 6955.77 -8437.74 298.21 7773.09 10005.58 7003.38 -8521.89 2.50 2.50 2.50 2.50 2.50 5986327.39 5986383.69 5986436.35 5986485.28 5986530.38 713044.46 712965.69 712884.50 712801.07 712715.55 N 70.36559535 W148.26884698 N 70.36575521 W148.26947371 N 70.36590533 W148.27012088 N 70.36604545 W148.27078713 N 70.36617525 W148.27147122 RECEIVED MAR 2 8 2001 ~,~ {~li & ~s Cmos. Commission Page I of 2 3/22/2001-4:03 PM Grid Coordinates Geo~lraphic Coordinates (ft) (o) (o) (ft) (fi) (ft} (ft) (°/lOOft) IftUS} IftUSI 14400.00 75.17 295.62 7798.65 10099.99 7047.14 -8608.09 2.50 5986571.58 712628.10 N 70,36629453 W148.27217194 14500.00 75.17 293.04 7824.25 10195.24 7086.96 -8696.17 2.50 5986608.77 712538,89 N 70.36640304 W148.27288790 14600.00 75.19 290.45 7849.83 10291.14 7122.77 -8785.96 2.50 5986641.91 712448.08 N 70.36650058 W148.27361773 14700.00 75.25 287.86 7875.34 10387.51 7154.49 -8877.29 2.50 5986670.92 712355,86 N 70,36658695 W148.27436003 14800.00 75.33 285.28 7900.74 10484.16 7182.08 -8969.98 2.50 5986695.76 712262.40 N 70.36666202 W148.27511335 14900.00 75.44 282.70 7925.97 10580.91 7205.47 -9063.87 2.50 5986716.36 712167.86 N 70.36672561 W148,27587638 15000.00 75.58 280.12 7950.99 10677.58 7224.62 -9158.76 2.50 5986732.70 712072.45 N 70.36677761 W148,27664751 15100.00 75.75 277.55 7975.76 10773.98 7239.50 -9254.49 2,50 5986744.75 711976,33 N 70,36681794 W148.27742541 15199.10 75.94 275.00 8000.00 10869.07 7250.00 -9350.00 2.50 5986752.42 711880.56 N 70.36684630 W148.27820149 15200.00 75.92 274.98 8000.22 10869.93 7250.08 -9350.87 2.50 5986752.47 711879.68 N 70,36684652 W148.27820856 End Crv Drp 4/100 15300.00 74.05 273.27 8026.12 10964.92 7257,03 -9447.19 2,50 5986756.57 711783,21 N 70.36686518 W148.27899119 15400.00 72.19 271.52 8055.15 11058.47 7261.04 -9542.79 2.50 5986757.76 711687.53 N 70.36687580 W148.27976793 15500.00 70.35 269.73 8087.26 11150.40 7262.08 -9637.49 2.50 5986756.00 711592.85 N 70.36687831 W148.28053734 15550.37 69.43 268.82 8104.58 11196.04 7261.49 -9684.78 2.50 5986754.01 711545.60 N 70.36687653 W148.28092154 16109.76 69.43 268.82 8301.11 11700.23 7250.70 -10208.40 0.00 5986727.76 711022.55 N 70.36684516 W148,28517559 End Drp Top Tuffs Top HRZ 16200.00 65.82 268.82 8335.45 11780.55 7248.99 -10291.81 4.00 5986723.58 710939.23 N 70.36684018 W148.28585324 16300.00 61.82 268.82 8379.56 11866.92 7247.14 -10381.52 4.00 5986719.08 710849.62 N 70.36683479 W148.28658207 16345.54 60.00 268.82 8401.70 11905.23 7246.32 -10421.31 4.00 5986717.09 710809.87 N 70.36683240 W148.28690534 16347.54 60.00 268.82 8402.70 11906.90 7246.28 -10423.04 0.00 5986717.00 710808.14 N 70.36683228 W148.28691939 17247.54 60.00 268.82 8852.70 12657.25 7230.23 -11202.30 0.00 5986677.93 710029.74 N 70.36678537 W148.29325031 Top Kuparuk Target / Crv 3/100 17545.54 60.00 268.82 9001.70 12905.69 7224,92 -11460.32 0.00 5986665.00 709772.00 N 70.36676980 W148.29534653 17545.54 60.00 268.82 9001,70 12905.69 7224,92 -11460.32 0.00 5986665.00 709772.00 N 70.36676980 W148.29534653 17600.00 59.88 270.70 9028.98 12951.27 7224.72 -11507.45 3.00 5986663.41 709724.90 N 70.36676905 W148.29572944 17700.00 59.72 274.17 9079.30 13035.76 7228.39 -11593.78 3.00 5986664.53 709638.50 N 70.36677872 W148.29643087 17800.00 59.66 277.64 9129.78 13121.10 7237.27 -11679.63 3.00 5986670.87 709552.43 N 70.36680261 W148,29712847 End Crv 17832.96 59.66 278.79 9146.43 13149.37 7241.34 -11707.78 3.00 5986674.10 709524.17 N 70.36681361 W148.29735723 Kup Z1A 18789.54 59.66 278.79 9629.70 13970.77 7367.47 -12523.62 0.00 5986776.07 708705.00 N 70.36715459 W148.30398725 TD/7"Lnr Pt 18789.54 59.66 278.79 9629.70 13970.77 7367.47 -12523.62 0.00 5986776.07 708705.00 N 70.36715459 W148.30398725 Legal Description: Surface: 1250 FSL 1125 FEL S36 T12N R15E UM Tie-In: 1999 FSL 3216 FEL S26 T12N R15E UM Target: 3186 FSL 2024 FEL S27 T12N R15E UM BHL: 3327 FSL 3087 FEL S27 T12N R15E UM NodhinqPC) rflus] Eastinq{X) 5979782.16 721440.24 5985594.38 713893.53 5986665.00 709772.00 5986776.07 708705.00 rftUSl NK-07A (P7) report,xls Page 2 of 2 VERTICA~ SEC~IONVI~W Client: Alaska Drilling & Wells Well: NK-07A (P7) Field: Niakuk Structure: Main Pad Section At: 284.52 deg Date: March 22, 2001 Schlumberger 2000 4000, 6000 8000 13042 MD ~ TVD Tuffs 16348 MD 8403TVD Proposal -- Survey c::) Tie-In Survey12721 MD 73~8TVD 59.20° 313.10° az 8649 de ~a~ture ~ TopofWindow12780M. D 7358TVD i ~ 59.74' 313.82° az 869: :~'~'~[u--C~"e ............................................................ i / Base WhipstoCk12796 MD 7366 TVD i , / 60.09' 311.64 az 8706departure ~ / ~ End Cr, 13073 MD 7471 TVD / / - 75.94' 312.95' az 8932departure Crv 2.51tlN) 13728 MO 7630 ~/D j ¢ 75.94' 312.95' az 9490dep~ture ...... i End Crv 15550 MD 8105 3V ................... ;!;~ 6~.43; 2'68.8~;az i1196de arture 7372 TVD ~-'~' Drp 4/'100 16110 MD 8301 '[~D 311.64°az 8715departure . ! " 69.43' 268.82'az 11700(._,~?.re_ HoldAngl, 75.9~4° i _. End Brp16346 MB 840~TVD ~ ~-60.00' 268.82'az 1190~ departure __ { old A (::]1 "'" 60.00'Ta'~'~et ~'~:rv268.~2, az~'10~;17546 MD ~:)02 TVD iH 12906 departure ~: :.. :...: ::::..:.: ..no.e ..... ~: _: :.: .: : ........ End Cr~17833 MD 9146TVD .... '~ '' 59.'66' ~.278;79' az 13149 deparlure NK-07' ~ NK-27 -~-~ nn'~- ' L-o -.~-,~_~/[ TDIT'LnrPI18790MO 9630TVD Hold gle 60.00° ~ ~9.66. 278.79'az 139?1departure 14000 2000 4000 6000 8000 10000 12000 VeKical Section Depa~ure at 284.52 deg from(O.O, 0.0). (1 in = 2000 feet) PL,~I v'rE~ Client: Alaska Drilling & Wells Well: NK-07A (P7) Field: Niakuk Structure: Main Pad Scale: 1 in = 2000 ft Date: 22-Mar-2001 Schlumberger A A A I-- 6000 O z 4000 2000 -12000 -10000 -8000 -6000 4000 -2000 0 ! i ! TD / T" Lnr Pt End Crv NK-27 End Crv i ~ True North 59.66' 278.79~ az 59.66' 278.79' az 69.43' 268.82' az ~ 7367N 12524W 7241N 11708W / 7261N 9685W ~ Crv 2.51100137~8 MD 7630TVD ~ ' i ] / [ ~ 75.94" 312.95'iaz 6682N 8073W ~ k / ...... ' End Crv "1307~ MD 7471 TVD : j X / ~ i ~ 75.94' 312.9~az 6249N 7608W ..-~ ~/ / EndDrp / ...... %% i '~'~' -'/ j Top ~fWindow12780 MD 7358TVDI j TargetlCrv31'(0(,,~ 16346MD 8402TVD ,u,r,p~l,.U~ ...... ~ ! ~/~/ 59.7? 313.82"az 6068N 7409W - ~ i ~ i ...................................................................................................................................................................................................................... i I I i -12000 -10000 -8000 -6000 -4000 -2000 0 8000 6OOO 4000 <<< WEST EAST >>> NK-07A Ri.qsite RECEIVED Summary of Drillin.q Hazards POST THIS NOTIOE IN THE DOGHOUSE oi~,~ O~s co,~s. Anchorage C°r~rnission HYDROGEN SULFIDE- Heald Point Niakuk Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Highest level of H2S measured on NK Pad: 60 ppm from NK-28. Highest level of H2S from adjacent wells at Surface: 44 ppm from NK-08. Highest level of H2S from adjacent wells at TD: 44 ppm from NK-08. The NK-07A well path will drill full sections of the Tuffs and HRZ shales. Both of these formations have been troublesome in the Niakuk area and have shown severe hole instability problems. Follow all shale drilling practices to limit high ECD's. We will also be using increased mud weights and shale stabilizers in the drilling fluid. The Kuparuk reservoir pressure is expected to be 4400 psi (9.4 ppg EMW) at the NK-07A bottom hole location. Because of the high mud weights required to drill the surrounding shale intervals, we will be drilling this interval with mud weights up to 10.9 ppg (~700 psi overbalance to Kuparuk). Based upon offset drilling data, losses are not expected, however monitor the well closely while drilling this interval and be prepared for potential losses by having fiberous LCM products on location. Because of the high mud weights required to drill the surrounding shale intervals, differential sticking will be a problem if the drill string or casing is left stationary for an extended period of time across the permeable West Sak or Kuparuk Sands. The kick tolerance for the 8Y2" open hole section would be an infinite influx assuming a kick from the Kuparuk at ~17,546' MD. This is a worst case scenario based on an 9.5 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the 9-5/8" window, and 10.9 ppg mud in the hole. Drilling Close Approach: All wells pass BP Close Approach guidelines. The nearest close approach well is NK-27 which is ~296' well-to-well at 15,593' MD and passes under Major Risk rules. Note tolerance lines and allowable deviation from planned NK-07A well-path. CONSULT THE Niakuk PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 NK-07A Hazards and Contingencies Page ! of 1 H DATI 01~901 PYMI' HANDL E ATTACHED CHECK INVOICE ,' CR[:Dll ME(~O DESCRIPTION GROSS, DISCOUNT NFl KO12901J 100. O0 100. 0O MMENTS' Per nit To Drill :ee INST' S/H - Terri Hubb[e X462B PAY~ F~ ~m ~"'BED ABOVE. ~ I 00. O0 100 _ O0 NC BP EXPLORATION (ALASKA), INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND ANAFRLIATE OF NATIONAL CITY BANK CLEVELAND, OHIO , '56-389 412 No. H 18.Z134 t CONSOLIDATED COMMERCIAL ACCOUNT~ii::: O0184'349 PAY T° Th e ORDER ONE HUNDRED & ******************************************** US' DOLLAR ALASKA OIL AND,,"OAS' CONSERVATION COMMISSION 333 'WEST 7TH AVENUE.: SUITE 100 ANCHORAOE AK 99501 DATE :'AMOUNT 0~/~1/01 ] $100.00[ NOT',VALID AFTER 120 DAYS WELL PERMIT CHECKLIST COMPANY ,/~',/~ WELL NAMF__,,~/~-~ ,r-- · FIELD & POOL ~'~/O / ~ ~' INIT CLASS ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. GEOL AREA ~".,~ UNIT# /"//~ N N N N N ENGINEERING ann. disposal para req_ Y N ~ ) ON/OFF SHORE GEOLOGY AT 23. If diverter required, does it meet regulations .......... ~i~ ~ I~ ' ~ w',~.'~-~ -- ,.. .._ 24. Drilling fluid program schematic& equiP list adequate ..... N 25. BOPEs, do they meet regulation ....... : . ..~ ... .... 26. BOPE press rating appropriate; test to t.~r,..,T,~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ............ Y (~'~9 '\ ~' 29. Is presence of H2S gas probable ..... . ............ .3~ \~, ~'-~: <~,,,.,.. 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... Y.,,,dq 32. Seismic analysis of shallow gas zones .............. ~,,,~¢ N ./(.),-~--/ 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports[explorato~nly] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: O z O -.I c:\msoffice\wordian\diana\checklist (rev. 11/01//00)
