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2003 Greater Kuparuk Area
ConocoPhillips April 1, 2004 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 Re: 2003 KRU Annual Surveillance Report Dear Mr. Seamount, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO-1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 In compliance with Rule 3, Conservation Order No. 19813, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Unit, is hereby submitting the annual surveillance report on the Kuparuk River Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2003. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, of produced and injected fluids, including low molecular weight hydrocarbons (Attachment 2, Attachment 3). c. Analysis of reservoir pressure surveys taken in 2003 (Attachment 4). d. A tabulation of both injection (Attachment 5) and production (Attachment 6) logs and surveys analyzed during 2003 from wells in the Kuparuk permit area. e. Composition of enriched gas injected during 2003 and estimate of MMP (Attachment 7). f. Kuparuk LSEOR development plan (Attachment 8). If you have any questions concerning this data, please contact Robert Christensen at (907) 659- 7535 or Stephanie Dobson at (907) 265-1561. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files ATO-1220A Attachment 1 Kuparuk River Unit Kuparuk River Oil Pool 2003 Annual Surveillance Report Summary of the Enhanced Recovery Project ENHANCED RECOVERY Miscible water -alternating -gas (MWAG) continues as the predominant FOR process at the Kuparuk field. In 2003, the FOR project expanded to four new drill sites: 1 B, 1 L, 3G, and 3S. The total number of MWAG drill sites in Kuparuk is 32. The field continues to manufacture miscible injectant (MI) at two of its Central Processing Facilities (CPF's). MI manufacture occurs by blending together produced lean gas and natural gas liquids (NGLs). NGLs originate from two sources (1) the Kuparuk field itself (known as indigenous NGLs), and (2) imported from Prudhoe Bay. Importation is utilized to fill any shortfall between total NGL requirement and indigenous NGL production. Due to the superior performance of the MWAG process over the Immiscible Water -Alternating Gas ([WAG) process, the Kuparuk FOR project continues to maximize the manufacture of MI by blending all available lean gas with NGLs. There was no IWAG injection at Kuparuk in 2003. Total MI injection into Kuparuk averaged 236 MMSCFD for 2003. The incremental oil production resulting from MWAG at Kuparuk averaged 33 MBPD in 2003. The Greater Kuparuk Area utilized an average of 15 MBPD of indigenous NGLs and 29 MBPD of imported NGLs to manufacture 305 MMSCFD of MI, of which 69 MMSCFD was supplied to the GKA satellite fields Tarn and Meltwater. The priorities for gas management for the Kuparuk field in 2003 were: 1) Focus MI injection into newly expanded MWAG patterns (A and C sands), and 2) Focus MI injection into patterns close to full maturity. In 2000 and 2001, the GKA satellite fields of Tarn and Meltwater, and Kuparuk A sand patterns received an increased share of the total GKA MI volume. Field performance indicated that gas storage efficiency was greatest in these reservoirs and producing zone. This gas storage effect caused the GKA gas production in 2002 and the first half of 2003 to be less than expected, however, it also maximized oil production during the same period by increasing producing days since wells were shut-in less time for gas handling. In 2002 and 2003, the GKA continued to manufacture less MI as gas production continued decreasing. An emphasis was made to inject MI into mature C sand patterns to maturate those patterns to completion earlier than expected, thereby, terminating MI injection into those patterns. The higher throughput of the C sand injection increased GKA gas production, and thus, increased MI manufacture in the second half of 2003. This additional MI manufactured has since been re -allocated back into a balance of mature and immature Kuparuk A and C sand patterns as well as the GKA satellites to optimize the FOR flood as well as keep the CPF compressors loaded to maximize MI production. MWAG Small Scale FOR (SSEOR and SSEORX) Drill Sites 1A, 1Y, and 2Z continued MWAG during 2003. The 2003 average MI injection rate was 15 MMSCFD. To date, these drill sites recovered over half of the ultimate incremental reserves through the MWAG process. Page 1 of 4 Large Scale FOR (LSEOR) The original LSEOR Drill Sites include: 1 F, 1 G, 1 Q, 1 R, 2A, 213, 2C, 2D, 2F, 2G, 2H, 2K, 2M, 2T, 2U, 2V, 2W, and 2X. The total MI injection rate into these drill sites averaged 143 MMSCFD in 2003. CPF-3 FOR DS3F was not part of the original LSEOR scope, but was approved shortly thereafter for MI injection. The 2003 average MI injection into DS31F was 11 MMSCFD. FOR Expansions CPF-3 has four additional drill sites on MWAG: DS313, 3H, 30, and 3Q. CPF-1 has two additional drill sites 1 C and 1 E. The combined average MI injection into these expansion drill sites is 48 MMSCFD. The Kuparuk FOR project was expanded to Drill sites 1 B, 1 L, and 3G in mid-2003. The combined 2003 annual average MI injection into these drill sites was 16 MMSCFD. The new Kuparuk Drillsite 3S initiated MI injection into one well, 3S-16, in October 2003. This FOR Drillsite expansion was accelerated from 2005 to 2003 after evaluation of the Drill site 3S waterflood performance. The 2003 annual average MI injection into DS 3S was 3 MMSCFD. Only one gas pipeline connects DS 3S to its neighboring drill site. Due to this piping configuration, when DS3S goes on MI gas for injection, the artificial lift gas used is also MI. The 2003 annual average MI gas rate used for artificial lift at drill site 3S was less than 1 MMSCFD. IWAG The Kuparuk FOR project continues to maximize MWAG operation by blending all available lean gas for MI. No IWAG operation is currently undertaken. Page 2 of 4 CA) 2� 2N i Tam) 1 2 P 2003 EOR Program Status GKA Activ, e EOR Patterns 276 KRU 15 Tam • 2 Meltwater SSEOR and SSEORX LSEOR and LSEORX EORX1 Expansion in 2001 EORX1 Expansion in 2002 ? 4 Wells GKA Satellites 1998-2002 EORX1 Expansion in 2003 1 C WSak EOR Pilot 2003 Potential Future Expansion - EORX2 GKA Activ, e EOR Patterns 276 KRU 15 Tam • 2 Meltwater Attachment 2 Kuparuk River Unit Kuparuk River Oil Pool 2003 Annual Surveillance Report Produced Fluid Volumes Attachment 2 Kuparuk River Oil Pool 2003 Annual Reservoir Surveillance Report Produced Fluid Volumes OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR MSTB MMSCF MSTB MSTB MMSCF MSTB 1 2003 5,023 9,188 13,811 1,865,117 1,070,986 2,118,699 2 2003 4,399 7,966 12,973 1,869,516 1,078,952 2,131,672 3 2003 5,043 8,968 14,330 1,874,560 1,087,919 2,146,002 4 2003 4,879 8,652 13,406 1,879,439 1,096,571 2,159,409 5 2003 5,277 9,260 14,399 1,884,716 1,105,831 2,173,808 6 2003 4,915 8,218 13,972 1,889,631 1,114,049 2,187,780 7 2003 4,750 8,240 13,230 1,894,381 1,122,289 2,201,010 8 2003 5,107 9,376 16,024 1,899,487 1,131,665 2,217,034 9 2003 4,780 8,636 14,932 1,904,267 1,140,300 2,231,966 10 2003 4,854 9,082 15,455 1,909,121 1,149,382 2,247,421 11 2003 4,674 9,457 15,178 1,913,795 1,158,839 2,262,599 12 2003 4,836 10,415 15,940 1,918,631 1,169,254 2,278,539 2003 TOTAL 58,537 107,456 173,651 Cumulatives at Dec 31, 2002 1,860,094 1,061,798 2,104,888 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR MRVB MRVB MRVB MRVB MRVB MRVB 1 2003 6,179 6,977 14,054 2,294,094 1,366,390 2,155,988 2 2003 5,411 6,030 13,201 2,299,504 1,372,420 2,169,189 3 2003 6,203 6,748 14,583 2,305,707 1,379,168 2,183,772 4 2003 6,002 6,504 13,643 2,311,709 1,385,672 2,197,415 5 2003 6,490 6,938 14,653 2,318,199 1,392,611 2,212,068 6 2003 6,045 6,056 14,218 2,324,245 1,398,666 2,226,286 7 2003 5,842 6,151 13,465 2,330,087 1,404,817 2,239,750 8 2003 6,281 7,128 16,305 2,336,368 1,411,945 2,256,055 9 2003 5,878 6,533 15,194 2,342,246 1,418,478 2,271,249 10 2003 5,971 6,946 15,727 2,348,218 1,425,424 2,286,976 11 2003 5,749 7,400 15,446 2,353,966 1,432,825 2,302,422 12 2003 5,939 8,287 16,122 2,359,906 1,441,111 2,318,544 2003 TOTAL 71,990 81,699 176,610 Cumulatives at Dec 31, 2002 2,287,915 1,359,412 2,141,934 Attachment 3 Kuparuk River Oil Pool 2003 Annual Surveillance Report Injected Fluid Volumes Attachment 3 Kuparuk River Oil Pool 2003 Annual Reservoir Surveillance Report Injected Fluid Volumes WATER GAS MI CUM WATER CUM GAS CUM MI MO YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF 1 2003 17,345 0 6,692 4,154,621 1,058,152 682,845 2 2003 16,564 0 6,305 4,171,186 1,058,152 689,150 3 2003 18,998 0 7,023 4,190,184 1,058,152 696,173 4 2003 17,523 0 6,784 4,207,706 1,058,152 702,957 5 2003 17,926 0 7,844 4,225,633 1,058,152 710,801 6 2003 17,280 0 6,931 4,242,912 1,058,152 717,732 7 2003 16,644 0 6,721 4,259,557 1,058,152 724,453 8 2003 17,318 0 7,472 4,276,875 1,058,152 731,924 9 2003 16,485 0 6,972 4,293,360 1,058,152 738,896 10 2003 15,906 0 7,591 4,309,266 1,058,152 746,487 11 2003 17,426 0 7,723 4,326,692 1,058,152 754,210 12 2003 19,426 0 8,273 4,346,117 19058,152 762,483 2003 TOTAL 208,841 0 86,330 Cumulatives at Dec 31, 2002 4,137,276 1,058,152 676,153 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR MRVB MRVB MRVB MRVB MRVB MRVB 1 2003 17,650 0 5,019 4,227,201 931,165 512,133 2 2003 16,853 0 4,729 4,244,054 931,165 516,862 3 2003 19,329 0 5,267 4,263,383 931,165 522,129 4 2003 17,828 0 5,088 4,281,211 931,165 527,217 5 2003 18,239 0 5,883 4,299,450 931,165 533,101 6 2003 17,581 0 5,198 4,317,031 931,165 538,299 7 2003 16,936 0 5,041 4,333,967 931,165 543,339 8 2003 17,621 0 5,604 4,351,587 931,165 548,943 9 2003 16,772 0 5,229 4,368,360 931,165 554,172 10 2003 16,183 0 5,693 4,384,542 931,165 559,865 11 2003 17,729 0 5,792 4,402,271 931,165 565,657 12 2003 19,794 0 6,205 4,422,066 931,165 571,862 2003 TOTAL 212,514 0 64,748 Cumulatives at Dec 31, 2002 4,209,552 931,165 507,115 Attachment 4 Kuparuk River Oil Pool 2003 Annual Surveillance Report Reservoir Pressure Surveys O "0 Y U1 J Q LL 0 w Q co M O N F 2 O IL W cr cc N m W 2 a O K W ch 2 z Z z a 0 O m 0 a n O O M O M r M V M n M N r n n O W r W M O O M O N V M w m O N M O n n N 7 M M M O V CO (DM c0 V O m V o O E m (0 N 0) M O m 00 m N t` 00 a2 O N V m N t` r N c0 O N H is ch N, Cl)N co M cn N N N co r r M M N N Cl) N N M N M Cl)V M d � a � 0 U a (o O M r N O M .- O m r r cD V .- O M m M M i1 too m a ,tm m N M n M� w N co M M m N N 'IT -It N r ,tN V N Vt r cV M N ItN M O C N O � Q � J 0 U) 0m0M000000000r nM 0r 000 OOM O V MOOWN O000"TOOMOOONN 00 mOM 0 M m cc M 0) O N M M O M O O O 0) M (D M wM M O h V N o 0) r M O) (D r 0 0 O 0 0 C7 M N N N N r N N M M M (D N N N 'V r Cl) -It 7 -It N N V r r r LO (0 O y r N m � H c C al 7 0 N O O O O O M (0 <t O m m M M O M N O O M M O O M O M O r V m M 0 7 0 m r O W M r 0 0 et O O O M M M O O M O N O M M r O M (0 CO 00 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Cn a Cn FL Cn a N a Cl) a Cn LL L1L i' Cl) co Cl) Cl) M M COco co co M Cl)M M 0 J W W LL > O 0) $O O O L- OD O O 0 to O 2OO I- 2 O �O O O M ('M co L- o W O N O O M M \O QO _ N r N C d Cn m O (0 0) (ON O O O m N (D O r O N 00 O O (D (D (D (D m O O O O O Z LLJ 0 n co (D O W M Q co O OD 00 (D OD (n 0) Q) 00 \0 � � V aD OD co m (� 00 W N � H O N O O 0 O !R O N O N O r Q z o Z r O O O O0a r0 O N O0 QO N O O O O O O O O O O O O O O 0 O O O O O O O O O O O O O O cr� OD � Cl) 00 a) co 0 (D 0) a) W N (D 00 O M '7 t` n 0) O M M (D m V V V V N O O O O M V N N N N N N N N N N N N N N _ d Z) 0) 0) 0) 0) 0 coM (M M 0 0) 0 0) (n O Q Z (n N O N O N O N O N O O r O r O r O r N O N O N O N 0 N 0 Lr J W It co N N N 0 (D r N It N co N J 0] r O O r r r N O O O O O O r W U LL LL LL L TZ I: M CM Z) co co co Cl) co co Cl)C co co OM') M CO Z - � / _§ 0LL §E�cc �a0IL =acc>- c cr > z §E/§) =�<nz <o>zz §IE�\ §2w0 YR§® cc /\ \/ /if \\\ z z 0<w \< /< ®®) § u P 2M c k ƒ a§ f 7 D U) / _ Eiw & + 0Eƒ 0 ! <a/ j } m a- _ (�\ z E _ < cn / §6 § / / uLL> \ j§§ \ 0< \ � FPe \ \z » _ $ \ U \ 8 § 7 \ \G � § \/\)A _jE m \ § / m z Attachment 6 Kuparuk River Oil Pool 2003 Annual Surveillance Report Production Survey Data m m 0- Cn w -i co LL J O v O Q FOrt¢t- z W CL w001=co co > °ELLJ (n ar > O V o D w Q G N Y > O J Q cr ccQ � a O Q CL Z Y Y o W a U J 0 Q U Iq N M (.� (O O co OD N N U') to to 0 �' h N M Cl) co co (D (D N N 0 a) f� � fl r M N 00 0) co N N N r r r r Cl) Z O UIt �- d co O m D) 00 00 N N O N N N� Lr)_ O OD V Co (� T � V co CJ j m �F N N f� h N N F) N T ifl «� V - _ m m M Cl) O (O r N to N M N r r M co O > m d J_ a- OD O O 00 to to V V (D (D 00 N N O N V Cl) h 7 V O O O Om h 0 to W CA h I� O O m r 7 co co N N n r (D (D to r N M COO r r Co N r N N r r (fl V 1� r N r N N n 7 Cn Z U U U U U U U U U U U U U Z O + Q + Q + Q + Q + Q + Q + Q + Q + Q + Q + Q + Q + Q O CC U Q Q Q Q Q Q Q Q Q Q Q Q Q N 0- Z O a) (2) (1) m a) CD m (1) CD ro a) (1) w 0) O) m 0) O 0) 0) C Cl)) ) 0) 0) 0) J W C_ C C C_ C_ C_ C_ C C_ C_ C_ C_ W J } (n (n U) (n U U)Cn (n �_ Cn Cn (n cn > IL ~ N N W O (n d Cn CL)d (n (n Cn a) (n a) Cn Cn N m N (n N cn N (n U Cn Cn Cn U) Cn Cn O CO Z z Z (n Z Z Z (n (n (n (n (n J } W 0- Q_ (n Q Cn Q Vi F Q Cn Q (n Q (n H F F- t F O LL > U U U a U U LL a a a a Cl) Er w w w ct)U Q `� U U (n U) U w Cn w � w � U U U U U w a a a a a a a 0 0 0 0 0 0 U U U U U U w a } Q F I J Q cr a } W Ir w Z d cn U) � U) ¢ W Z a- (n U) � � rr W Z 0- Cl) rL W Z LL (n cr W Z IL (n rr cr W W Z Z CL CLo (n (n LL O W J i- W M O ro OO Cl) O Cl) 2 M OO CM O 07 OO co O co O Cl) O M O M Cl) O O W C] LL o (L > m = (n O) O V O co N O rl N to O N N (D O 0) O O O co O 0)N O O M r O Q) O m r n O O N N O OD r p r- 0) O O Z LL O F Q 0 Q F Z 0 H U o O co M T 0) N O M rn rn N O Cl)V 0) r m O V rn N O coV rn r m V O co rn r V' rn N O V co rn (n N r O tl O O O O O O O O O O O O O O O O O O O O O O O O O O CC O O to r I- O O to t- V N W w N _N N V M Cl) Cl) co O Kt N O m _O N N N O N N N N N N N N N d O D) N O N D) N O N D) N Q) N O N D) N Cl) O D) N D) N D) O N N Q Z to O O O O O O O O O O O O m J W co V' O N 0) r Cl) to 7 N J m r O r O r N N N N O O r r O cc } } } } m m N N N Z I �,M N W J J CO LL J O v 0 a Z M LLJ CL 0 J 0 Y :� cr w O O cc H � > w > U � O U a Z) a C\l Y a 0 I a Q � C 0 a z Y Y O W z U J 7 2 0 0 LO LO O 00 7 'IT O 0 co 0 O M O (j (n tM 00 Cl)O N M M z O jW F- d N co 0 (0 O N N 00 to 0 Ih r i- O to 0 O V 0 0 O N O O eT V 00 O 0 0 n r M M 0 as o M M M M 00 O N 00 (O Cl) r r O > m r Er a _J 0 co a) m Ln 00 0 (O O O V' O N O N N LL O O I- n N r O) N Ih 0 0 00 a)O (O 0)O 00 O m N N r r N N CO Cl) n N M N Itto LO cn w Q z U U U U U U U U U U z0 O + a + a + a + a + a + a + a + a + a + a cl:U a a a a a a a a a a N d D Z O m (D a) a) (3) (1) a) a) a) w o) CD o) m a) o) m d o rn J w C_ C C C_ C_ C_ C_ C C_ w J } Cn U) cn U) Cl) cn cn Cn Cn a U O cn CO Cl) (n cn (n to (n (n U U U) U fr 0 0 0 O Z LL J w a a F- Z U) � -i J J J J J J Cn O LL O Er U U d cn a cn d cn d cn cn a cn a U) U cn a `�0 w w U) W w a a a a a a a o U U U d Lj } fL w cr Ir CC cr Ir J W W W W w W w w a O x w c%j Z Z Z Z Z Z Z N F' Q Cr d 0 U d U d U IL0- cn U) d U IL Cl) ILU C/) LL O J } W co O (7 !R co O co O cM O M O M O co O co O co O FO LL > r 00 O U') r (7 r m r o N 00(O N N m N O N a D a D 0 C' o V 0 O O LO 0 m 0 O) 0 m 0 m 0 N O z LL O Q O N M V cM M M M V co Krp w tT N O O 0) tT m tT M m m F a Z 0 0 T N O T N O T N O d C LL a 0 o O O O O O O O 0 O O O o O 0 O o O O cc w M a m O) O 00 r V r M V V r O O O O (A. _ d Z) N O) N 0) N O) N O) N O) N 0)m N N Cl) N Cl) N m a Z O to N O N O N O N O N O N O O O O N O n J J W cc O 00 r to o M 0 0 to o (0 O 00 r r 00 r LLJ N N Q m LL LL 0 (D 2 z N N ce) M M co Cl) Cl) (Y) M Z Attachment 7 Kuparuk River Oil Pool 2003 Annual Surveillance Report Miscible Injectant Composition Conservation Order 198B Rule 3. Kuparuk River Unit Reservoir Surveillance Program Miscible Injectant (MI) compositions and corresponding Minimum Miscible Pressures (MMP) for the three CPF's are presented in the table below. No MI composition data is reported for CPF-3 for 2003 because MI manufacture at CPF-3 ceased in 2000 with the installation of the 1Y Jumper Line. This jumper enabled the expansion of the FOR Project to IDS 1 Q, 30 and 3Q, as well as continued MI supply to DS-3F. MI is now supplied to the CPF-3 drill sites from both CPF-1 and CPF-2. The MMP of the blended CPF-1 and CPF-2 MI is estimated on a monthly average basis and is reported in the attached Table in the column for CPF-3. Prior to 2001, CPF-3 manufactured a small amount of MI for DS-317 with indigenous NGL's. Now, these CPF-3 indigenous NGL's are routed to the wet oil line for transport to CPF-1 and 2 for stabilization in the GKA sales oil, or else recovery as indigenous NGL for reuse within the FOR project. Minimum Miscible Pressures of MI Supplied to Each CPF MMP Target Spec = 3300 psia CPF1 CPF2 CPF3* CPF3 MI Source Month CALC MMP** (psia) CPF1(%) CPF2(%) Jan-03 3027 3384 3384 0 100 Feb-03 3039 3258 3258 0 100 Mar-03 3333 3270 3284 22 78 Apr-03 3282 3393 3340 47 53 May-03 3574 3764 3697 35 65 Jun-03 4158 3311 3311 0 100 Jul-03 3274 3315 3303 29 71 Aug-03 3778 3376 3397 5 91 Sep-03 3227 3450 3436 6 94 Oct-03 3235 3343 3333 9 91 Nov 03 3262 3467 3415 25 75 Dec-03 3271 3369 3329 41 59 Average 3372 3392 3374 14 86 * Calculated **Considers NGL pump downtime & gas compressor downtime Attachments of individual CPF MI compositions follow. M r r CD M O O O O O O O O M CO N CD (O No O O O O O O O U 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O O O O O O O O O O O O O O O O O O O O N 0000000000000 U 0 0 0 0 0 0 0 0 0 0 0 0 0 0000000000006 0000000000000 T 0000000000000 U 0 o o o o o o o o o o o o o O O O O O O O O O O O O 0 0 0 0 O O 11 O In "t 'ct O O O O O O r N N r r N N U 0 O 0 0 0 0 0 0 0 0 0 0 0 0600000666666 O M M N O CO N t` n T r p M C11 M T CO � O OD n M n n M rt � () r r 0 0 0 0 r M N r r N N 0000000000000 I'- N It M O M (O It N O t- M r 00 M M'lt d N (O N M M I r () O w CO tt r t� � r O In r*.� 00 M r 0 0 0 0 0 0 r r o o 0 o M O NKt n M In M r M CD n O't M N n N m co 0 N N M O (� O (O N M CN (O 7 M n n (O 00 N r r O O r r N ----- m O (0 N If) 109 M N r r p r T � N r r T r r r LL a U w 0 n M OM N r M M It O r r It M" N iCf i MN_OWN°M OZ N N r- - r- N N N N N N N N P (n Lc) m (D It m c0 M O N't It n M �t CO O OO N O N CO M M lf) � M N �? n a (C) M (D Ci O pl� co M OR Cn M ao 00 L C T T T T r T T T T T T r T Z O LU _ N M T O I1) 00 M d LO M O M L) CO r In N M N co O M O t- � In � O to M M 00 In N M M In 00 Z (O O (fl In v (D (O (D (D n n (D (O tUU r= Q r'IT N N 'd' M n LO r a n n It to r M d' OD OD 00 N M LO LU V M It M d' d' d' In N N (fl n It In > N N N (NJ N N N N N N N N N Y t� It M M C') -t (D (O co co co Lp It P- U COO ONO N ~ C) (D00Mf - M 00 CC) i Q Ct Lo n r T co co If) In (n Lo If) (.() a Y M r CO M Co Cl) CD It CO OD CO (O In N� 00 In O 00 00 00 n T N O 00 N (� In O n n CO 'ct N O N M T (D co t-- n M 6— n nr,� n n n t-� CO n CD (O N In M n M II) Cl) 00 M N n In T 'It (.0 (O (O O r I.f) 00 N U�00 0't►;0)00nN0)ItCO�t 00 n 00 4 4 n r-� n M n n M M (O (O O (O CO (D (O CO (O M (D CO CO M lf) n n r r N 0 n't M N (y r r M (O (D r M M It M N r r Z I: M C? If) Ln M M N CM N M M M O O O O O O O O O O O O O N O M t� Cn Ifj M� r Cp N Lf) O M ��OMn�} �tMvin�aoln 0 � 00 00 In d; n 00 CO 00 ap 00 M 00 V 0 0 0 0 0 0 0 0 0 0 0 0 0 ------------- LL LL LL LL LL LL LL LL. LL LL LL LL LL UILdLLdLLCLILIla11LLda- m U C) C)U U U C)U U U U U C) ce) M c7 M M M C'') M Cl) (') ('M M C'') 0 0 0 0 ... 00 00000 0 N 0 0 0 0 0 0 00 0 0 0 m N N N N N N N N N N N Nin c`V co M M (D O M C� O M r O rN N C�7 N C� � -M In In n n M 'a) T FOR ANALYTICAL REPORT KUPARUK LABORATORY CONOCOPHILLIPS ALASKA INC. Facility CPF-1 Sample Date 8/23/2003 Distribution: Sample Time 14:47 14:55 14:35 Line Pressure 300 1500 3800 Line Temp. NA NA NA SETCIM Tag FI-20GC FI-21GC Calculated Flow (MSCFD) 15529 62708 78237 Component Solvent (Lab) (Mole %) Lean Gas (Lab) Mole %) MI (Target) (Mole %) MI (Lab) (Mole %) MI (Calc) Mole CO2 0.357 1.153 0.993 0.852 0.995 N2 0.005 0.360 0.289 0.287 0.290 C1 7.588 83.218 68.052 67.953 68.206 C2 6.415 7.487 7.272 7.218 7.274 C3 11.820 4.210 5.736 5.858 5.720 iC4 9.020 0.889 2.520 2.681 2.503 nC4 26.556 1.868 6.819 7.305 6.768 i C5 7.944 0.347 1.870 1.954 1.855 nC5 9.992 0.327 2.265 2.364 2.245 C6 8.900 0.085 1.853 1.112 1.835 C7 7.231 0.056 1.495 1.721 1.480 C8+ 4.172 0.000 0.837 0.690 0.828 Total Moles 100.00 100.00 100.00 100.00 100.00 M W 62.39 Density (lbs/scf) 37.16 Actual ENFL Rate Rate (lb/d) 2549675.53 Rate (Mol/d) 40865.79 Rate (MMSCFD) Target Blend Gas Ratio (lb BG/lb EF) Actual Blend Ratic (From measured flow rates) Youngren MMP 20.28 28.73 28.60 Ideal BG Rate Actual Gas Rate 3304769.816 3347432.03 162917.899 61908801.62 Actual MMP (Using Lab MI Composition) Calc MMP (Using Lab BG/ENFL comp and rates) 1.30 1.31 3300.00 3315 3327 M r N N m r-O O O O O O O O O CD (n O O O O O O O O � V r 0 0 0 0 0 0 0 0 .000 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O O O O O O O N �O O O O O O O O O O O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 V 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 T 0 0 0 0 0 0 0 0 0 0 0 0 0 T 0 0 0 0 0 0 0 0 0 0 0 0 0 V 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O Lt7 r O M [t O 00 U0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 00 M M O O 00 M It N N r- V' O V O O D O O 7 7 N N 7 7 N 7 O O O O O 0 0 0 0 0 0 0 0 M h (D (D r- CO O M M M O Op M (O lC) r O O M to Cn O N V CA (� r r- (n CD CD rll� OD 0A Cb t` r-1, 00 rl: 0000000000000 M M M r M O CD O It N W CO t 0 r r r (O M M r M LO r T T r T r T T T r T T r r N O N M 00 (DN CD n (D � M lf) CA M Lo [t C0 00 00 !� N O () O CD CD Lo CD r, r r O 0A Cn O O r r r T r r r T r O O r r N LL d N O a' M N Cn M 00 N 00 r� U V O N O r M N r 0 0 r- Z Z N N N r CV N N CV CV N CV CV N O �- N M CD LO 00 M Cl) CO N O 'It O N 00 CD r- O 0) N 00 CD Cl) ci rl- r-- cO 't r- CO Cn N: r� n (O r� (0 tia -rrrrTTrrTT.=rr O w T O (n N CD M O r- It CO M r- i M LO It M O w r- LO N V 00 O ti O O O ti m m r- (O rl_ (� Z cD cD CO O O Cn O cD O O O O O aZ Q 00(ONr-Orl- OMN(DODCT) I�r mmr�OMMO NOr-M V M C0 0') (D CO M It M M It N N N CV N CV N CV N N N N N CV Y LO 00 It CO CO 00 CO O I�T N (O 00 O M O) t (D ct O M M M M T CO Q C.) O M t` N r r (O N M CD (n N r rZ Ln Co Lri co r N LO LO LO LO Lr) LO LO Y Cn (n tp CO CD O r� (n r M r O M N N Cf) 00 �Y CA CA N r r r r� O V r O d' d' M T to N M I Cn M M r� r r oo rn O r,� r-� r r--: r,� r- r-- CD M r rl- r N O t M M M M 00 It It r CO T CD �t M r- M 0 T r (0 M N � � r, (n 0n CO O (D CD 0 O CD (D (D CD (0 (D O CD r- 0Mr-0* 14-r-r-M0MM N 0 t` r- r M (fl - (O (0 (0 r- M 0 Z N N NNMNNNNNNN 0 0 0 0 0 0 0 0 0 0 0 0 0 NOMr-OO(ONr- NN r-Nr-- 00r-LO"t(0r`rl- O(0r L) CD Cn O M Ln Cn (D (D (D (O (0 (O (0 V 0 0 0 0 0 0 0 O C C O O O Y N N N N N N N N N N N N N = LL LL LL LL LL LL LL LL LL LL LL LL LL ZmMCLMa- mmmmmmMIL LL U U U U U U U U U U U U U M M M M 07 M M M M M M M M 0 0 0 0 0 0 0 0 0 0 0 0 0 D N N N N N N N N N N N N N T O M N N N ` r M N iF2 N N T a T C� (M lA l!') (O 1� r� OD 0) r Mr cc 0 a W J Q . V0z LL Y J m (n Q J J Z Y Q CE Q 0. Q J a W N,d y (i (n is � N N N N N C1 m m Cl N N d m E E E E E E E E E E E E U O m 4mj y N- N y N N N N N N O O O O O N O O O O O O O Z Z Z Z Z Z Z Z Z Z Z Z _x C V� 0 0 6V- U' o O N O (D (D n N O 10 M C0 co O p m 0 ap.. (� LO r O N O) (D (D n 0 0 CD M M O O M N N O O O 0 Q LL r m 0 0 CO 6 O r 6 0 0 0 0 0 °a m x_ co O (D w H _co N j 0 "G r c d O co Cl) YV O N W O N N T n (() 0 N N 0 U O �: Ci _ �ro�rrio N N O o0000a U(' LL a v w w a m 00 �' U v(Or i CO'M71 iM n(ncov.o ZoWm-Nonowo0 co„onN GN <�NtOtCgC4fC A� O Gi.,� h'.4ti LV W N U 0 Q O Z N m J co :lam , 0, m N (O tN O ^. T O O N OOi N CO n t N N O <T CD O M M Z M N a LL r 0 � O n (D O OM) M n O M( l0 M O CD M n N M Cl)M V O OMD M OMf (A CD CD F O O O 10 n ui N 1- r N r r 0 0 CD rn w N Z m� o o 0 n n w N v 0 0 to M (`. M 0 (+j r .- N 0 a O ONi O N N 0 0 0 6 a 0 0 CO 6 O N 0 0 0 O O co O LL V O v m n 00 m�� co m MM rn M°*n° 0(n(no cv N N M O N O (n 0 T M G j N �fi O(n T vim. O M O N N n Cl V D Z 206 666 O N COr �m V 0 LL d i o N OlLL o G ,'m N OU D n Z U U c V � U U V V O N N c 0 as FU"c%�;U 2 , E m ro F- 3 NR75 m c c o m w o (nJ J(n LL0[- F-- O N coco N 00 06 N N N ui a a N m Q) G m O m 0 m o a� (D m—° N U m R 2 U m N i7 O m 2 Ch �a O M[ m CM') M:j 7 O O tl M M O au C.7 O ' O (D NO•N 7 r< 00 (D . N Q O C_ LO U-) m MN cc o L C7tco 0 - DiN Cl) �O(0ern LL w y m 00 �r Cl o CD m NE C a D E m CO CC 00 N OD '-_ O a J J ?. CL 110 c, c a.; E Z Ow r W M r O Uj 7 U (7 m m rn,0 E m m U N Y. Q a` m m c 3 v O 0.: O _ . ,co CL O O Xcc w a'm-a� Sm�v a o� aci n3d c�CL IL a_ rn-23 C ( O N m 01. 7 c 7 .2 20 ¢¢¢ F F'Q YQU Attachment 8 Kuparuk River Unit Kuparuk River Oil Pool 2003 Annual Surveillance Report Development Plan for LSEOR Attachment 8 Kuparuk River Oil Pool 2003 Annual Surveillance Report LSEOR Development Plan During 2003, the Greater Kuparuk Area (GKA) averaged 29 MBPD of PBU NGL imports and 15 MBPD of indigenous NGLs for an annual average of 305 MMSCFD of Miscible Injectant (MI) manufacture. Of the GKA manufactured MI volume, 236 MMSCFD was distributed to Kuparuk: 154 MMSCFD to LSEOR drillsites (including 3F), 15 MMSCFD to SSEOR and SSEORX drillsites, and 67 MMSCFD to LSEOR expansion drillsites. The remaining 69 MMSCFD was distributed to the GKA satellites. LSEOR expansion drillsites include drillsites: 1 B, 1 C, 1 E, 1 L, 3B, 3G, 3H, 30, 3Q and 3S. Currently MI is injected into all of the 21 drillsites sanctioned under the LSEOR project and the CPF-3 FOR expansion drill site 3F. The LSEOR expansion to drillsites 1 B, 1 L, 3G, and 3S occurred in 2003. A West Sak (DS1C) FOR pilot was performed in the second half of 2003 and additional pilot work will continue in 2004. Further drilling activity in the Kuparuk River Oil Pool potentially provides new opportunities to maximize field recovery while preventing physical waste. Drilling opportunities are under constant evaluation as the field matures, geologic and reservoir performance information is assimilated and as technology improves. The Kuparuk FOR project may be expanded to include any new wells. ConocoPhillips April 1, 2004 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO-1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Kuparuk River Oil Pool — Proposed Pressure Survey Plan for 2004 Dear Mr. Seamount, In compliance with Rule 8, Conservation Order No. 432, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Oil Pool, is hereby submitting the proposed pressure survey plan for 2004. There were 204 pressure surveys reported for the Kuparuk River Oil Pool to the AOGCC in 2003. In 2004, we expect to conduct approximately 180 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Robert Christensen at (907) 659-7535 or Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files ATO-1220A ConocoPhillips April 1, 2004 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7" Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO-1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Kuparuk River Oil Pool — Proposed Injection Profile Survey Plan for 2004 Dear Mr. Seamount, In compliance with Rule 4, Conservation Order No. 19813, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Oil Pool, is hereby submitting the proposed injection profile survey plan for 2004. In 2003, 43 injection profile surveys were reported for the Kuparuk River Oil Pool to the AOGCC. In 2004, we expect to conduct approximately 40 injection profile surveys, including initial surveys. If you have any questions concerning this data, please contact Robert Christensen at (907) 659-7535 or Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files ATO-1220A . r ConocoPhillips March 31, 2004 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 71h Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO-1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Kuparuk River Oil Pool — 365+ Days Shut In Well Report Dear Mr. Seamount, In compliance with AOGCC Regulation 20 AAC 25.115(a), ConocoPhillips Alaska, Inc., as operator of the Kuparuk River Field, is hereby submitting our 365+ days Shut In Well Report. The attached document lists all wells in the Greater Kuparuk Area that have been shut in for more than 365 days. 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C c t C C r C c O C r_ O y O O O � O (n O 3 O— Q O 00 O O O O S 0 D i Q C C c U O C c X Q c X C C C c c 0 C C Lo 0 C a O C Ln -0 O C tf) p Y Y �C Q) N 0 .1 .Y — Y Q Y N Y Y Y Y Y Y p Y Y r O V QZZZLiSUZZI�- F- ZHZS Z M Z Z Li ZZ� Z LLZ�LLO� N C T o oL1 w000pWwo0Wowm W O ww Lit W W W W W O W N t lC � N C i 7 N N N O O O N N N M m _ (O Cp (O co N ,C O O p C? C? C? 0 0 0 O O O O O M M T O p fn a R (D 0 0 00 o c'an.�__6' m (n�)o00 ZZZU)Z Q 0 OQ Q 0 a> N ppr<MQQQ co I to CD 1l- 00 O O r rr E Z O N N r r O r �t r CC) N (D 77 �M(p�pCppO>00>000 p r r N r > > >0>0>0 >C) LLLLLL co co M LL M M M M M M �UN M M LL M M M M 3 E E 0 Q / r_ / k k 0 E 2 % » / / 0 \ \ 7 / 2 co \ 0) c « E \ \ 7 \ 0a \\ \ \\ § / ( \ S S ) ' § / / \ 2 / 2}CO E \ \ 'a 0 k � § & \ % /-a \ \ ( CL m S 0 C e / t $ > § / E= c E % ` - c $ 2 o° / E 2 3\S} E cE �7/ }° ° / 2§ c 3 7 \ f o= \ �� 6E/ o �\ m 7 \ y °�/�\ k� \\Cf) -0(Da) c 0 m 0 CO Gng° a = So®&/� _ }S elk\ƒ = o � @ ®g7 § ]kE2E<± �«I-j Q7 LL3/2/f3 2¥6862 w± wwaaa ConocoPhillips April 1, 2004 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Kuparuk River Oil Pool - Proposed Pressure Survey Plan for 2004 Dear Mr. Seamount, In compliance with Rule 8, Conservation Order No. 432, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Oil Pool, is hereby submitting the proposed pressure survey plan for 2004. There were 204 pressure surveys reported for the Kuparuk River Oil Pool to the AOGCC in 2003. In 2004, we expect to conduct approximately 180 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Robert Christensen at (907) 659-7535 or Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files ATO -1220A ConocoPhillips April 1, 2004 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Kuparuk River Oil Pool — Proposed Injection Profile Survey Plan for 2004 Dear Mr. Seamount, In compliance with Rule 4, Conservation Order No. 198B, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Oil Pool, is hereby submitting the proposed injection profile survey plan for 2004. In 2003, 43 injection profile surveys were reported for the Kuparuk River Oil Pool to the AOGCC. In 2004, we expect to conduct approximately 40 injection profile surveys, including initial surveys. If you have any questions concerning this data, please contact Robert Christensen at (907) 659-7535 or Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files ATO -1220A ConocoPhillips March 31, 2004 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Kuparuk River Oil Pool — 365+ Days Shut In Well Report Dear Mr. Seamount, In compliance with AOGCC Regulation 20 AAC 25.115(a), ConocoPhillips Alaska, Inc., as operator of the Kuparuk River Field, is hereby submitting our 365+ days Shut In Well Report. The attached document lists all wells in the Greater Kuparuk Area that have been shut in for more than 365 days. It also lists the reason the wells were shut in as well as the mechanical condition of the well and any future plans. These wells are different from the suspended wells, which have a separate report. If you have any questions concerning this data, please contact Robert Christensen at (907) 659-7535 or Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files ATO -1220A Greater Kuparuk Area 365 -Day Shut-in Well Report 2003 Annual Submittal Well Name Date Shut -In Reason Well Shut -In' Current Mechanical Condition of the We112 Future Utility Plans & Possibilities Comments 1D-119 Mar -02 E No known problems 6 Reservoir Management 1 E-05 Feb -95 E No known problems 3 Low Injectivity / Fill in Tbg / Flowline corrosion / Flowline removed 1 E-08 Jun -00 E Flowline corrosion 1 Flowline repair under evaluation 1 E-09 Feb -01 E Flowline corrosion 3 No immediate plans to fix flow line 1E-10 Nov -93 D Plug Stuck in Tbg 3 Flowline removed 1E-12 Apr -01 B Collapsed tbg 3 Future sidetrack potential 1E-13 Oct -01 E Flowline corrosion 3 No immediate plans to fix flow line 1E-14 Oct -90 E No known problems 3 Unable to inject or flow / Flowline removed 1E-15 Dec -02 E Flowline corrosion 1 Potential sidetrack to support 1 F-19 1E-16 Mar -00 E Flowline corrosion 3 Low priority to fix flow line 1E-17 Jul -97 D Flow cut C sand mandrels 3 Flowline removed 1E-19 Feb -98 D Flow cut C sand mandrels 3 Not injecting, downhole trouble 1 E-25 Sep -94 E No known problems; MITIA 10/14/00 3 Low Injectivity / Flowline removed 1 E-26 Dec -97 D Suspect Liner Damage 2 Plan to flowtest - ST possible 1 E-29 Nov -98 D Casing leak at 3300' 1 Potential workover 1 E-30 Aug -96 D Fish in Tubing Tail 3 Low Injectivity past fish / Flowline removed 1 F-02 Mar -00 D Flowline corrosion/ Tbg x IA Communication 1 Evaluating workover 1F-11 May -01 D OA x OOA Communication 3 sundry 10-403 approved for casing repair Well is SI with TTP in SBR and DV is pulled. 1 F-15 Apr -02 E Flowline corrosion 2 Included in GKA'04 Flowline Up ra e- Phase 1 1 G-08 Nov -02 D Collapsed tbg 1 Sidetrack candidate 1 H-401 Aug -02 D Failed ESP 2 Waiting on pump redesign 1 L-01 Oct -98 E No known problems; MITIA 10/14/00 1 Sidetrack & flowline repair 1 L-25 May -96 E No known problems; MITIA 10/14/00 1 Reservoir Management. Evaluating possible sidetrack. 1M-17 Ma -02 E No known problems 6 Appraisel Well, evaluating'04 extended test. 10-01 Dec -99 E No known problems 6 Reservoir Management 1Q-15 Jan -00 E No known problems 1 Low Injectivity / Injector to Producer Conversion Candidate R i Page 1 of 4 Greater Kuparuk Area 365 -Day Shut-in Well Report Page 2 of 4& 2003 Annual Submittal Well Name Date Shut -In Reason Well Shut-in' Current Mechanical Condition of the Wel12 Future Utility Plans & Possibilities Comments 1 R-09 May -99 E Bradenhead Leak; MITIA 10/14/00 1 Low Injectivity 1 Y-24 Sep -02 D Liner damage 1 Sidetrack Candidate 213-10 Jul -01 E No known problems 3 Reservoir Management 2D-14 Jun -00 E Tbq x IA Communication 6 Reservoir Management 2E-05 Apr -94 C No known problems 4 No future plans 2E-06 Apr -94 C No known problems 4 No future plans 2E-07 Oct -94 C No known problems 3 Ice Plug In Tubing / Low Volume Cold A Sand Oil 2E-09 Nov -93 D Ice Plug In Tubing/ Hole In Tubing 1 May Make It A 2F Injector 2E-17 Apr -94 C No known problems 4 No future plans 2F-06 Mar -02 D Casing Damage 1 Sidetrack Candidate 2F-14 Oct -02 E No known problems 6 Reservoir Management 2F-16 Apr -00 E No known problems 6 Reservoir Management 2F-17 Jul -00 E No known problems 6 Reservoir Management 2F-19 Sep -01 C 09/23/01: POT -IC, PPPOT-T and MITOA all failed 3 Uneconomic To Produce 2F-20 Jun -98 B No known problems 2 Watered Out Lisburne Test / Ready to Complete In Kuparuk Zone 2G-06 Mar -01 C No known problems 3 Uneconomic To Produce 2H-02 Jun -02 E No known problems 6 Reservoir Management 2L-03 Apr -02 C No known problems 3 No Future Plans 2M-18 Dec -99 D Hole In 7" Casing at 7041' 1 RWO Candidate 2M-23 Sep -97 E No known problems; MITIA 10/12/00 3 Disposal 2N-345 Dec -02 C No known problems 1 Sidetrack Candidate 2T-32 Dec -02 E No known problems 6 Reservoir Management 2T -38A Jan -01 C No known problems 3 Uneconomic To Produce/Freezes 2T-210 Jun -00 D Tubing Damage 1 Tabasco Water Injection Well 2U-09 Jan -00 C No known problems 1 Producer to Injector Conversion 2X-19 Nov -01 C No known problems 3 Uneconomic To Produce/Freezes 2Z-03 Apr -02 E No known problems 6 Reservoir Management 2Z-16 Jun -97 D C Sand CSM Broken (Leaks) and Possible Packer Leak 1 If C Sand Iso Needed Patch Broken C Sand CSM 2Z -WS -1 Oct -86 C No known problems 3 West Sak Test Producer 3A -03A Jun -01 D&E Tbg x IA Communication 1 A sand won't flow post CTD ST 3A-17 Oct -02 D No known problems 3 SI due to low flow rates 3C-07 Jun -01 D Flowline corrosion 3 Poor economics to repair flowline 3C-09 Nov -02 D Flowline corrosion 6 WO flowline repair 3C-15 Jan -02 D Flowline corrosion 3 WO flowline repair Greater Kuparuk Area 365 -Day Shut-in Well Report 2003 Annual Submittal Well Name Date Shut -In Reason Well Shut-in' Current Mechanical Condition of the We112 Future Utility Plans & Possibilities Comments 3F-09 Sep -02 D IAxOAxAtmos comm. 4 SI and secured 3F-20 Jul -02 E No Known Problems 6 Drilling depressurization 3F-21 Aug -02 E No Known Problems 6 Drilling depressurization 3G -19A Jun -02 D No known problems 2 SI for high solids production 3F-19 Dec -01 D Failed RWO 1 ST planned 3H -10A Oct -00 D Hole collapsed during CTD ST 1 ST planned 3H -14A Oct -00 D CTD lost BHA in hole 1 ST planned 3H -25A Jun -99 E No known problems 4 Suspended Sidetrack 31-16 Nov -00 E No known problems 6 Reservoir Management 3J-17 Nov -02 D Tbg x IA Communication 1 Mult. Tbg holes 31VI-03 Nov -02 D T x IA comm 1 no inflow post screen installation 31VI-16 Sep -01 E No known problems 6 Reservoir Management 3M-18 Nov -02 D TxlAxOA comm 2 Evaluate for Patch 3M-26 Jun -01 E No known problems 6 Reservoir Management 30-19 Jan -01 D Hole in casing 2 Troubleshooting leaking csg patch CPF2-WDW Aug -89 E No known problems 3 Disposal WSW -01 Apr -83 D Packer Problems 3 Will not be used for injection WSW -02 Mar -94 E No known problems MIT 10/5/97 3 Will not be used for injection WSW -03 Jul -01 E No known problems MIT 10/5/97 3 Will not be used for injection WSW -04 Aug -96 E Failed MITIA 04/27/96 3 Will not be used for injection WSW -05 Jul -01 E No known problems MIT 10/15/00 3 Will not be used for injection WSW -06 Jul -94 E No known problems; MITIA 10/05/97 3 Will not be used for injection WSW -07 Jul -01 E No known problems MIT 10/5/97 3 Will not be used for injection WSW -08 Oct -96 E Failed MITIA 05/24/93 3 Will not be used for injection WSW -09 Oct -96 E No known problems; MITIA 10/15/00 3 Will not be used for injection WSW -10 I Apr -83 I D JFailed MITIA 3 Will not be used for injection WSW -11 Aug -92 —11 E No known problems; 10/05/97 3 Will not be used for injection ♦ ,. Y Page 3 of 4 Greater Kuparuk Area 365 -Day Shut-in Well Report 2003 Annual Submittal 1. Reasons for Well Shut -In A. High GOR, curently uncompetitive to produce due to facility constraints, no known mechanical problems B. High water, currently uneconomic to produce, no known mechanical problems C. Low production rate, no known mechanical problems D. Mechanical Problem E. Other (Specify under comments) 2. Current Mechanical Condition Briefly describe the current mechanical condition including the condition of installed tubing and casing strings. 3. Future Utility 1. Evaluating remedial, sidetrack and/or redrill opportunities 2. Remedial well work planned 3. Long term Shut-in well/ No immediate plans 4. Suspended well 5. P&A planned 6. Other (Specify under comments) Page 4 of 4 Reason Well Current Mechanical Condition Future Utility Plans Well Name Date Shut -In Shut-in' of the We112 & Possibilities I Comments 1. Reasons for Well Shut -In A. High GOR, curently uncompetitive to produce due to facility constraints, no known mechanical problems B. High water, currently uneconomic to produce, no known mechanical problems C. Low production rate, no known mechanical problems D. Mechanical Problem E. Other (Specify under comments) 2. Current Mechanical Condition Briefly describe the current mechanical condition including the condition of installed tubing and casing strings. 3. Future Utility 1. Evaluating remedial, sidetrack and/or redrill opportunities 2. Remedial well work planned 3. Long term Shut-in well/ No immediate plans 4. Suspended well 5. P&A planned 6. 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Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO-1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax:(907)265-6133 Re: 2003 West Sak Oil Pool Annual Reservoir Surveillance Report Dear Mr. Seamount, In compliance with Rule 11, Conservation Order No. 406A, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Field, is hereby submitting the annual report on the West Sak Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2003. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, for produced and injected fluids (Attachment 2, Attachment 3). c. Analysis of reservoir pressure surveys taken in 2003 (Attachment 4). d. Results of production surveys, and any special surveys, taken on the West Sak Oil Pool in 2003 (Attachment 5). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6). f. Future development plans (Attachment 7). If you have any questions concerning this data, please call Hai Hunt at (907) 265- 6912, or Bob Christensen at (907) 659-7535. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files ATO — 1220A Attachment 1 Kuparuk River Unit West Sak Oil Pool 2003 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project West Sak development activities in 2003 included drilling eight horizontal wells; five producers and three injectors. The 2003 development drilling program led to expansion of the West Sak development area to a new surface pad location, Drillsite 1 B. Both a water injector and a producer were drilled from Drillsite 1 B. At the end of 2003, there were 29 water injectors and 29 producers in service in the West Sak oil pool. The following wells were drilled in 2003 in the West Sak oil pool: Name Well Type Target Inj/Prod 1 C-178 Multilateral B/D Sand Producer 1 C-170 Horizontal D Sand Producer 1 C-172 Horizontal, Undulating A2/A3/A4 Sand Producer 1 C-184 Horizontal D Sand Producer 1 C-174 Horizontal, Undulating B/D Sand Injector 1 C-190 Horizontal D Sand Injector 1 B-101 Multilateral B/D Sand Producer 1 B-102 Horizontal, Undulating B/D Sand Injector Waterflooding the reservoir with CPF-1 produced water for pressure maintenance and improved sweep continues to be the main enhanced recovery mechanism in the West Sak oil pool. Waterflood performance has been good, with production response in both vertical and horizontal producers indicating pressure support and most of the Phase I and Phase II producers showing water breakthrough by the end of 2003. During 2003, ConocoPhillips Alaska, Inc. received approval to commence a West Sak Small Scale FOR (SSEOR) Pilot Project using Kuparuk MI in a water - alternating gas (WAG) pilot. The SSEOR Pilot Project consists of three phases in two permitted areas: Phase I : WAG wellbore completion integrity test; Phase II : WAG injectivity test; and Phase III : WAG breakthrough test. Phase I of the Pilot Project was initiated on September 22, 2003 with the commencement of injection of Kuparuk MI into 1 C-135. Injection was continued for approximately two months. At the end of 2003, 1 C-135 was being prepared to return to long-term production. It is anticipated that in 2004 Phase I of the Pilot Project will be completed and that Phase II will begin. Attachment 2 West Sak Oil Pool 2003 Annual Reservoir Surveillance Report Produced Fluid Volumes OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2003 210888 36859 50220 7953131 2116703 1302690 2 2003 190945 47536 42528 8144076 2164239 1345218 3 2003 191412 42466 88959 8335488 2206705 1434177 4 2003 209593 42589 97140 8545081 2249294 1531317 5 2003 227788 43106 65026 8772869 2292400 1596343 6 2003 265086 52744 69407 9037955 2345144 1665750 7 2003 259013 68715 63663 9296968 2413859 1729413 8 2003 253879 76740 68431 9550847 2490599 1797844 9 2003 254351 76727 62639 9805198 2567326 1860483 10 2003 266003 108941 47808 10071201 2676267 1908291 11 2003 212905 86512 35923 10284106 2762779 1944214 12 2003 315034 129691 72350 10599140 2892470 2016564 2003 TOTAL 2856897 812626 764094 Cumulatives at Dec 31, 2002 7742243 2079844 1252470 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2003 225650 57034 50220 8509850 3243739 1302690 2 2003 204311 73831 42528 8714161 3317570 1345218 3 2003 204811 65683 88959 8918972 3383253 1434177 4 2003 224265 65637 97140 9143237 3448890 1531317 5 2003 243733 66592 65026 9386970 3515482 1596343 6 2003 283642 81878 69407 9670612 3597360 1665750 7 2003 277144 107647 63663 9947756 3705007 1729413 8 2003 271651 120233 68431 10219406 3825240 1797844 9 2003 272156 119977 62639 10491562 3945217 1860483 10 2003 284623 171829 47808 10776185 4117046 1908291 11 2003 227808 136478 35923 11003993 4253524 1944214 12 2003 337086 207473 72350 11341080 4460996 2016564 2003 TOTAL 3056880 1274291 764094 Cumulatives at Dec 31, 2002 8284200 3186705 1252470 Attachment 3 West Sak Oil Pool 2003 Annual Reservoir Surveillance Report Injected Fluid Volumes WATER GAS MI CUM WATER CUM GAS MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2003 529689 0 0 12741783 0 0 2 2003 474520 0 0 13216303 0 0 3 2003 437080 0 0 13653383 0 0 4 2003 400414 0 0 14053797 0 0 5 2003 417937 0 0 14471734 0 0 6 2003 486329 0 0 14958063 0 0 7 2003 524309 0 0 15482372 0 0 8 2003 647532 0 0 16129904 0 0 9 2003 514839 0 8915 16644743 0 8915 10 2003 528989 0 90094 17173732 0 99009 11 2003 529434 0 71830 17703166 0 170839 12 2003 676489 0 0 18379655 0 170839 2003 TOTAL 6167561 0 170839 Cumulatives at Dec 31. 2002 12212094 0 0 M 1 2 3 4 5 6 7 8 9 10 11 12 O Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI YR RVB RVB RVB RVB RVB RVB 2003 529689 0 0 12741783 0 0 2003 474520 0 0 13216303 0 0 2003 437080 0 0 13653383 0 0 2003 400414 0 0 14053797 0 0 2003 417937 0 0 14471734 0 0 2003 486329 0 0 14958063 0 0 2003 524309 0 0 15482372 0 0 2003 647532 0 0 16129904 0 0 2003 514839 0 6677 16644743 0 6677 2003 528989 0 67480 17173732 0 74158 2003 529434 0 53801 17703166 0 127958 2003 676489 0 0 18379655 0 127958 2003 TOTAL 6167561 0 127958 Cumulatives at Dec 31, 2002 12212094 0 0 k ) LLI Cl) § § j z « j Eco ƒ~R_]�2 f& > ) )/ ) 2 /0o & \]/ > £§o j G co 2 _/ $/ /)=e, \ §% o) _ a)ca / \ � ~ - , p a) . \ } )}600\ ) w _E \ 2 a. 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Ri N O t+l H O O W n fn n W N N (V H O Oq 01 a O N N N r� lfl O O O W m H W H H N F7 W I i i Page 1 of 5 Attachment 5 Kuparuk River Unit West Sak Oil Pool 2003 Annual Reservoir Surveillance Report Production Logs and Special Surveys Geochemical Production Splits: Well Name Date Split Gas Split Water Split Oil Split Layer Name 18-101 12/19/2003 0% 0% 0% A 1 B-101 12/19/2003 70% 70% 70% B 1 B-101 12/19/2003 30% 30% 30% D 1 C-102 4/17/2003 0% 0% 0% A 1 C-102 4/17/2003 41 % 41 % 41 % B 1 C-102 4/17/2003 59% 59% 59% D 1C-102 8/30/2003 0% 0% 0% A 1C-102 8/30/2003 62% 62% 62% B 1 C-102 8/30/2003 38% 38% 38% D 1 C-102 12/20/2003 0% 0% 0% A 1 C-102 12/20/2003 66% 66% 66% B 1 C-102 12/20/2003 34% 34% 34% D 1C-104 4/17/2003 0% 0%p 0% A 1C-104 4/17/2003 36% 36% 36% B 1 C-104 4/17/2003 64% 64% 64% D 1 C-104 8/30/2003 0% 0% 0% A 1 C-104 8/30/2003 62% 62% 62% B 1 C-104 8/30/2003 38% 38% 38% D 1 C-104 12/20/2003 0% 0% 0% A 1C-104 12/20/2003 43% 43%n 43% B IC-104 12/20/2003 57% 57% 57% D 1 C-109 4/17/2003 0% 0% 0% A 1 C-109 4/17/2003 60% 60% 60% B 1 C-109 4/17/2003 40% 40% 40% D 1 C-109 8/30/2003 0% 0% 0% A 1 C-109 8/30/2003 59% 59% 59%fl B 1 C-109 8/30/2003 41 % 41 % 41 %4 D 1 C-109 12/20/2003 0% 0% 0% A 1 C-109 12/20/2003 40% 40% 40% B 1 C-109 12/20/2003 60% 60% 60% D 1C-178 5/31/2003 0% 0% 0% A 1C-178 5/31/2003 44% 44% 44% B 1C-178 5/31/2003 56% 56% 56% D 1 C-178 8/30/2003 0% 0% 0% A 1 C-178 8/30/2003 46% 46% 46% B 1 C-178 8/30/2003 54% 54% 54% D 1C-178 12/20/2003 0% 0% 0% A 1C-178 12/20/2003 52% 52% 52% B 1C-178 12/20/2003 48% 48% 48% D 1 D 102 1 /15/2003 0% 0% 0% A 1 D 102 1 /15/2003 60% 60% 60% B 1 D 102 1 /15/2003 40% 40% 40% D Page 2 of 5 Geochemical Production Splits: Well Name Date Split Gas Split Water Split Oil Split Layer Name 1 D 102 4/28/2003 1% 1% 1% A 1 D 102 4/28/2003 70% 70% 70% B 1 D 102 4/28/2003 29% 29% 29% D 1 D 102 8/29/2003 0% 0% 0% A 1 D 102 8/29/2003 72% 72% 72% B 1 D 102 8/29/2003 28% 28% 28% D 1 D 108 1/15/2003 25% 25% 25% A 1 D 108 1/15/2003 53% 53% 53% B 1 D 108 1/15/2003 23%4 23% 23% D 1 D 108 4/28/2003 14% 14% 14% A 1 D 108 4/28/2003 57% 57% 57% B 1 D 108 4/28/2003 29% 29% 29% D 1 D 108 8/29/2003 21 % 21 % 21 % A 1 D 108 8/29/2003 51 % 51 % 51 % B 1 D 108 8/29/2003 28% 28% 28% D 1 D 110 1/15/2003 29% 29% 29% A 1D 110 1/15/2003 30% 30% 30% B 1 D 110 1/15/2003 41 % 41 % 41 % D 1 D 110 4/28/2003 54% 54% 54% A 1 D 110 4/28/2003 18%u 18% 18% B 1 D 110 4/28/2003 28% 28% 28% D 1 D 110 8/29/2003 2.80% 28% 28% A 1 D 110 8/29/2003 43% 43% 43% B 1 D 110 8/29/2003 28% 28% 28% D 1 D 112 1/16/2003 29% 29% 29% A 1 D 112 1/16/2003 50% 50% 50% B 1 D 112 1/16/2003 21 % 21 % 21 % D 1 D 112 4/28/2003 25% 25% 25% A 1 D 112 4/28/2003 54% 54% 54% B 1 D 112 4/28/2003 21 % 21 % 21 % D 1 D 112 8/29/2003 29% 29% 29% A 1 D 112 8/29/2003 48% 48% 48% B ID 112 8/29/2003 22% 22% 22% D 1 D 113 1/16/2003 21 % 21 % 21 % A 1 D 113 1/16/2003 21 % 21 % 21 % B 1D 113 1/16/2003 58% 58% 58% D 1 D 113 4/28/2-003 40% 40% 40% A 1 D 113 4/28/2003 30% 30% 30% B 1 D 113 4/28/2003 30% 30% 30% D 1 D 113 8/29/2003 39% 39% 39% A 1 D 113 8/29/2003 25% 25% 25% B 1 D 113 8/29/2003 36% 36% 36% D 1 D 115 4/28/2003 47% 47% 47% A 1 D 115 4/28/2003 42% 42% 42% B 1 D 115 4/28/2003 12% 12% 12% D 1 D 115 8/29/2003 48% 48% 48% A 1 D 115 8/29/2003 38% 38% 38% B 1 D 115 8/29/2003 14% 14% 14% D 1 D 116 1/14/2003 39% 39% 39%fl A 1 D 116 1/14/2003 40% 40% Ott%fl B 1 D 116 1/14/2003 21 % 21 % 21 % D Page 3 of 5 Geochemical Production Splits: Well Name Date Split Gas Split Water Split Oil Split Layer Name 1D 116 4/28/2003 42% 42% 42% A 1D 116 4/28/2003 50% 50% 50% B 1D 116 4/28/2003 9% 9% 9% D 1 D 116 8/28/2003 43% 43%b 43% A 1D 116 8/28/2003 46% 46% 46% B 1D 116 8/28/2003 12% 12% 12%© D 1D 118 1/14/2003 64% 64% 64% A 1D 118 1/14/2003 11 % 11 % 11 % B 1D 118 1/14/2003 25% 25% 25% D 1D 118 4/28/2003 74% 74% 74% A 1D 118 4/28/2003 12% 12% 12% B 1D 118 4/28/2003 15% 15% 15% D 1D 118 8/28/2003 77% 77% 77% A 1D 118 8/28/2003 6% 6% 6% B 1 D 118 8/28/2003 17% 17% 17% D 1D 121 1/15/2003 17% 17% 17% A I 121 1/15/2003 53% 53% 53% B 1 D 121 1/15/2003 30% 30% 30% D 1D 121 4/28/2003 34% 34% 34% A 1 D 121 4/28/2003 45% 45% 45% B 1 D 121 4/28/2003 21 % 21 % 21 % D 1D 121 8/28/2003 52% 52% 52% A 1 D 121 8/28/2003 35% 35% 35% B 1 D 121 8/28/2003 13% 13% 13%n D 1D 123 1/14/2003 43% 43% 43% A 1D 123 1/14/2003 57% 57% 57% B 1D 123 1/14/2003 0% 0% 0% D ID 123 4/28/2003 54% 54% 54% A 1D 123 4/28/2003 44% 44% 44% B 1D 123 4/28/2003 2% 2% 2% D 1D 123 8/28/2003 65% 65% 65% A 1D 123 8/28/2003 31 % 31 % 31 % B 1D 123 8/28/2003 5% 5% 5% D 1D 124 1/14/2003 43% 43% 43% A 1D 124 1/14/2003 48% 48% 48% B 1D 124 1/14/2003 9%9 9% 9% D 1D 124 4/28/2003 44% 44% 44% A 1D 124 4/28/2003 45% 45% 45% B 1D 124 4/28/2003 11 % 11 % 11 % D 1D 124 8/27/2003 45% 45% 45% A 1D 124 8/27/2003 41 % 41 % 41 %A B 1D 124 8/27/2003 14% 14% 14% D 1D 126 4/28/2003 57% 57% 57% A 1D 126 4/28/2003 43% 43% 43% B 1D 126 4/28/2003 1% 1% 1% D ID 126 8/27/2003 51 % 51 % 51 % A 1D 126 8/27/2003 49% 49% 49% B 1 D 126 8/27/2003 0%n 0% 0% D 1D 129 4/28/2003 57% 57% 57% A 1D 129 4/28/2003 41 % 41 % 41 % B 1D 129 4/28/2003 2% 2% 2% D Page 4 of 5 Geochemical Production Splits: Well Name Date Split Gas Split Water Split Oil Split Layer Name 1D 129 8/27/2003 62% 62% 62% A 1D 129 8/27/2003 28% 28%n 28'% B 1D 129 8/27/2003 10% 10% 10%© D 1D 131 1/14/2003 52% 52% 52% A 1D 131 1/14/2003 42% 42% 42% B 1D 131 1/14/2003 6% 6% 6% D 1D 131 4/28/2003 54% 54% 54% A 1D 131 4/28/2003 42%fl 42% 42% B 1D 131 4/28/2003 4%4 4% 4% D 1 D 131 8/27/2003 61 % 61 % 61 % A 1D 131 8/27/2003 30% 30% 30% B 1D 131 8/27/2003 10% 10% 10% D 1D 133 1/14/2003 30%Q 30%4 30% A 1D 133 1/14/2003 57% 57% 57% B 1D 133 1/14/2003 12% 12% 12% D 1D 133 4/28/2003 52% 52% 52% A 1D 133 4/28/2003 39% 39% 39% B 1D 133 4/28/2003 9% 9% 9% D 1D 133 8/27/2003 53% 53% 53% A 1D 133 8/27/2003 38% 38% 38% B ID 133 8/27/2003 9% 9% 9% D 1D 134 1/14/2003 49% 49% 49% A 1D 134 1/14/2003 35% 35% 35% B 1D 134 1/14/2003 '16% 16% 16% D 1D 134 4/28/2003 53% 53% 53% A 1D 134 4/28/2003 35% 35% 35% B 1D 134 4/28/2003 13% 13% 13% D 1D 134 8/27/2003 54% 54% 54% A 1D 134 8/27/2003 34% 34% 34% B 1D 134 8/27/2003 12% 12% 12% D 1D 135 1/15/2003 0% 0% 0% A 1D 135 1/15/2003 29% 29% 29% B ID 135 1/15/2003 71 %e 71 % 71 %Q D 1D 135 4/28/2003 6% 6% 6% A 1D 135 4/28/2003 35% 35% 35% B 1D 135 4/28/2003 59% 59% 59% D 1D 135 8/27/2003 5%4 5% 5% A 1D 135 8/27/2003 39% 39% 39% B 1D 135 8/27/2003 55% 55% 55% D 1D 140 1/15/2003 0% 0% 0% A 1D 140 1/15/2003 69% 69% 69% B 1D 140 1/15/2003 31 % 31 % 31 % D 1D 140 3/14/2003 1 % 1 % 1 % A 1D 140 3/14/2003 1 % 1% 1 %n A ID 140 3/14/2003 2% 2%Q 2% A 1D 140 3/14/2003 3% 3% 3% A 1D 140 3/14/2003 97% 97% 97% B 1D 140 3/14/2003 99% 99% 99% B 1D 140 3/14/2003 94% 94% 940% B 1D 140 3/14/2003 94% 94% 94% B 1D 140 3/14/2003 3% 3% 3% D Page 5 of 5 Geochemical Production Splits: Well Name Date Split Gas Split Water Split Oil Split Layer Name 1 D 140 3/14/2003 0% 0% 0% D 1 D 140 3/14/2003 4% 4% 4% D 1 D 140 3/14/2003 3% 3% 3% D 1 D 140 4/28/2003 2% 2% 2% A 1 D 140 4/28/2003 70% 70% 70% B 1 D 140 4/28/2003 28% 28% 28% D 1 D 140 8/29/2003 1% 1% 1% A 1 D 140 8/29/2003 72% 72% 72% B 1 D 140 8/29/2003 27% 27% 27% D 1 D 141 1/15/2003 0% 0% 0% A 1D 141 1/15/2003 6% 6% 6% B 1 D 141 1/15/2003 94% 94% 94% D 1 D 141 4/28/2003 5% 5% 5% A 1 D 141 4/28/2003 5% 5% 5% B 1 D 141 4/28/2003 90% 90% 90% D 1 D 141 8/29/2003 3% 3% 3% A 1 D 141 8/29/2003 6%fl 6% 6% B 1 D 141 8/29/2003 92% 92% 92% D Attachment 6 Wsak Oil Pool 2003 Production Allocation Factors Oil Gas Water Jan-03 0.9739 0.9608 0.9862 Feb-03 0.9630 0.9619 0.9975 Mar-03 0.9580 0.9464 0.9843 Apr-03 0.9586 0.9600 0.9760 May-03 0.9504 0.9528 0.9788 Jun-03 0.9496 0.9578 1.0671 Jul-03 0.9634 0.9602 1.0825 Aug-03 0.9578 0.9346 1.0744 Sep-03 0.9498 0.9362 1.0741 Oct-03 0.9442 0.9422 1.0633 Nov-03 0.9317 0.9355 1.0448 Dec-03 0.9444 0.9023 1.0280 Attachment 7 Kuparuk River Unit West Sak Oil Pool 2003 Annual Reservoir Surveillance Report Future Development Plans • DRILL SITE 1 E DEVELOPMENT DRILLING The KRU working interest owners intend to drill five to nine wells from Drill Site 1 E in 2004. Information regarding the wells is listed below: Name Well Type Target Inj/Prod 1 E-119 Vertical A2/B/D Sand Injector 1 E-123 Multilateral D/B Sand Producer 1 E-112 Multilateral A2/B/D Sand Injector 1 E-126 Multilateral A2/B/D Sand Producer 1 E-166 Multilateral A2/B/D Sand Producer 1 E-114 Multilateral A2/B/D Sand Injector 1 E-168 Multilateral A2/B/D Sand Producer 1 E-105 Multilateral A2/B/D Sand Injector 1 E-104 Vertical A2/B/D Sand Injector If drilling times are quicker than expected, it is possible that a tenth well might be drilled before year-end.. • DRILL SITE 1 J DEVELOPMENT ConocoPhillips has approved an AFE for a 37 well West Sak development at Drill Site 1 J and is working to secure approvals from the necessary percentage of working interest owners. If AFE approval by the Working Interest Owners is achieved by July, 2004, then development drilling would begin on or around Ap ri 1 1 st 2005. • WEST SAK FOR PILOT PROJECT PLANS An enriched hydrocarbon miscible gas FOR pilot is underway at Drill Site 1 C. The enriched hydrocarbon miscible gas for this project comes from the existing Kuparuk River Unit ("KRU") enriched hydrocarbon miscible gas supply. Miscible gas injection began in late 2003. Facility modifications have been made to Drill Site 1 C to accommodated West Sak EOR. ConocoPhillips April 1, 2004 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 71" Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO-1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: West Sak Oil Pool — Proposed Pressure Survey Plan for 2004 Dear Mr. Seamount, In compliance with Rule 8, Conservation Order No. 406A, ConocoPhillips Alaska, Inc., operator of the West Sak Oil Pool, is hereby submitting the proposed pressure survey plan for 2004. There were 6 pressure surveys reported for the West Sak River Oil Pool to the AOGCC in 2003. In 2004, we expect to conduct approximately 15 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Robert Christensen at (907) 659-7535 or Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files ATO-1220A
