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Home My WebLink About2010 Nicolai CreekAurora Gas, LLC November 30, 2011 Mr. Daniel Seamount, Chair )EC 0 5 2011 Alaska Oil and Gas Conservation Commission ��!}k�I C+' 333 West 7t" Ave., Suite 100 Ges Cons. Cori Anchorage, Alaska 99501 Anchegga s%on RE: Reservoir Surveillance Report and Reservoir Pressure Reports (Form 10-412) Aurora Gas, LLC: Nicolai Creek -South Undesignated and -Beluga Dear Commissioner Seamount: Aurora Gas, LLC hereby submits a Reservoir Surveillance Report and two Reservoir Pressure Reports for the pressures taken in 2010 at Nicolai Creek Unit No. 1 B, No. 2, No. 9, and No. 11 gas production wells in the Nicolai Creek Gas Field on the west side of Cook Inlet, as required by Conservation Order No. 478A. Please find enclosed the following information for your files: 1) Reservoir Surveillance Report (Combined for NCU- South and NCU- Beluga) for 2010; 2) Form 10-412 Reservoir Pressure Report for Nicolai Creek -South Undesignated for 2010; 3) Form 10-412 Reservoir Pressure Report for Nicolai Creek -Beluga for 2010; 4) Nicolai Creek Unit Pressure Map; and 5) Supporting information: P/Z vs, Cumulative Production Plots for #113, #2, #9 (2), and #11. If you have any questions or require additional information, please contact me at (281) 495-9957 by email at jejones.2aurorapower.com. . Sincerely, URORA GAS, J. Edward Jone President enclosures cc: Temple Davidson, ADNR-DOG 6051 North Course Drive, Suite 200 • Houston, Texas 77072 • (281) 495-9957 • Fax (281) 495-1473 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 NICOLAI CREEK UNIT WELLS NO. 113, 2, 9, and 11 RESERVOIR SURVEILLANCE REPORT RE: CONSERVATION ORDER NO. 478A HISTORYAND SUMMARY AS OF 12/31/10 :: �C$CZ1111�117 Aurora Gas, LLC re-entered and side-tracked the abandoned Texaco Nicolai Creek Unit (NCU) No. 1A in 2002 and completed the well in three Upper Tyonek sands, the Carya 2-4.2 at 3137-3157' TVD, the Carya 2-5.1 at 3307-3348' TVD, and the Carya 2-6.1 at 3506-3521' TVD. These intervals were commingled upon completion and tested with an AOF of 3.1 MMCfpd. Unfortunately, in spite of free -hanging sand control screens in the completion string, the well produced water and sand along with the gas, and, consequently, produced very little gas for sales to date. Unable to control the sand production by surface means, the well was recompleted in June of 2006: 1) plugging off the Carya 2-6 sand, from which the sand and much of the water was being produced (as evidenced by sand fill and a "sand -blasted" hole in the screen at that depth), 2) adding perforations to the Carya 2-3 sands at 2783-2864' TVD, the Carya 2-2.2 sands at 2550- 2568' TVD, the Carya 2-2.1 sands at 2426-2434' TVD, and the Carya 2-1.2 sands at 2254-2316' TVD, and 3) completing selectively (see attached well bore diagram). As of December 2006, the Carya 2-3 to the Carya 2-1.2 sands were mechanically open and producing (perfs at 2307-2918' MD, but some were plugged by sand --see note below Development plans), and the deeper sands, 2-4 to 2-5 (perfs at 3191-3401' MD) are shut in with a retrievable plug at 3184' in the stinger of the packer at 3145'. These open perfs have produced 282.6 MMcf of the 290 MMcf produced by this well through 12/31/10. The NCU No. 2 well was also re-entered by Aurora. Gas in 2002 and re - completed into the Upper Tyonek Carya 2-1.1 sand at 2141-2177' TVD, the Carya 2-1.2 sand at 2342-2354', and the Carya 2-2.1 sand at 2493-2511' TVD. These commingled intervals tested for a calculated AOF potential of 14.6 MMcfpd. A production facility and gathering line were constructed in 2003 and the well started producing to sales December 2003. The well has produced 768.5 MMcf since the re-entry thru 12/31/10. The NCU No. 9 was drilled on the same pad as the two directional wells above in 2003 to capture reserves behind two strings of pipe in the two old wells. It was completed in a Beluga Tsuga 2-7 interval at 1320-1447' TVD/MD (now the Middle Completion). This well tested yielding at calculated AOF potential of 49.1 MMcfpd. It also started producing to sales in December 2003 and produced 1071 MMcf from this Completion. Because this completion has depleted significantly, a recompletion adding additional Tsuga 2-8, 2-7, and 2-6 sands from 1148-1904' was completed in September 2006. The well produced 326 MMcf from the Lower Completion at 1552-1904' (9 different Tsuga 2-7 and 2-8 sands) between the recompletion in October 2006 and October 2008. In October 2008, the pressure of this Lower Completion had declined to near that of the Middle Completion, so the sliding sleeves for the Middle Completion were opened, allowing both the Middle and Lower Completions to produce commingled. The well has produced 1921.4 MMcf thru 12/31/10 of which 442 MMcf is allocated to the Lower Completion and 1479 MMcf to the Middle Completion. NOTE: All three of the above well are on the same pad, with the #113 and #2 being directional, so all have the same ground level elevation (22' AMSL) and nearly the same KB/DF elevation, so TVD's are very nearly TVDss and, thus, almost directly correlative. NCU #11—The Nicolai Creek Unit #11 well was drilled in September 2009 to a depth of 3600' (MD/TVD) and was completed on October 6, 2009, in 14 Beluga sands and 2 Upper Tyonek sands isolated by packers and sliding sleeves into 4 selective completions. The well was tested in the commingled completions in the Beluga Lower Tsuga 2-7 and 2-8 interval from 1736-2099' TVD and in the Upper Tyonek Carya 2-1 interval at 2260- 2362'. These commingled intervals were tested (4 -point) to give an CAOF of 5466 mcfpd with a static pressure of 924 psia (909 psig) at a datum of 2049' TVD (-2033' TVD SS). Production was initiated from the Tyonek Carya 2-1 completion in December 2009, and the well produced 11,281 mcf that month. Following commingling approval, the well produced from the Beluga and Tyonek perfs at 1736-2362', sometimes selectively, sometimes commingled. Two shallower selective completions were briefly tested upon completion and are known to be productive, but were not produced in 2010: these completions cover Beluga Tsuga 2-5 thru 2-7 sands at 1004-1675' TVD. Commingled production from the two completions is being allocated back to the Lower (Tyonek) completion at 30% and to the Lower Middle (Beluga) Completion at 70%, based volumetric reserves and supported by production test rates. The well produced 381.8 MMcf through 12/31/2010: 311.1 MMcf allocated to the Lower Middle (Beluga) Completion and 70.9 MMcf allocated to the Lower (Tyonek) Completion. CONSERVATION ORDER NO. 478A REQUIREMENTS This Order issued October 16, 2003, by the AOGCC has three items pertaining to reservoir surveillance at Nicolai Creek Unit wells No. 1B, No. 2, and No.9, requiring: 1) (0) Initial reservoir pressures, 2) (#4) Annual monitoring of reservoir pressures, and 3) (#5) Annual reservoir surveillance reports. INITIAL RESERVOIR PRESSURES Form 10-412's for both Pools (Nicolai Creek—South undesignated and Nicolai Creek—Beluga) for 2002 and 2003, show initial reservoir pressures. The initial reservoir pressures for #1B and #2 were obtained by bottom -hole pressure surveys (No. 1B and 2) and confirmed by quartz -crystal surface pressures extrapolated to subsea datum. These initial pressures were: #113-1625 psig at -3293' TVDss, and #2-1025 psig at -2285' TVDss. The #9 well was taken by quartz -crystal surface pressure recorder and was confirmed by open -hole MDT measurements—it was 673 psig at -1348' TVDss. Subsequent work, i.e., the 2006 recompletions of #1B and #9, added the following original pressures: #113-1211 psig at -2537' TVDss (commingled currently open perfs of Carya 2-2.1 to the 2-3 at 2480'- 2918' MD) and in #9-666 psig at -1706' TVDss (Lower Completion). The drilling of the #11 well in 2009 gave additional pressure information: it was tested in the commingled completions in the Beluga Lower Tsuga 2-7 and 2-8 interval from 1736-2099' TVD and in the Upper Tyonek Carya 2-1 interval at 2260-2362' with a static pressure of 924 psia (909 psig) at a datum of 2049' TVD (-2033' TVD SS). ANNUAL MONITORING OF RESERVOIR PRESSURES Attached are Form 10-412's for both Pools (Nicolai Creek—South undesignated and Nicolai Creek—Beluga) for 2010, showing annual reservoir pressures, along with some comments. Surface pressures have been used exclusively for annual pressures after initial pressures in Wells #2 and #9, which have made very little water, so they are consistently in single-phase condition. Surface pressures in #113 and #11 may be affected by some minor buildup of water in the wellbore, but no bottom -hole pressures were obtained in 2010. Note that due to the recompletions of #113 and #9 in 2006 and the subsequent production of different intervals, the datum TVDss's for these wells have changed since the 2006 submittals. Note also that the #11 well is included in these 10- 412 reports although it is in an different PA (West the Lower Middle (Beluga) completion is included in the Beluga Pool report and the Lower (Tyonek) Completion is included with the South Undesignated Pool. The reservoir pressure survey data and production data from the four producing wells have been plotted to yield P/Z vs. Cumulative Production curves, providing a material - balance projection of reserves. Those plots (using Ryder Scott Excel templates) are attached. These show the #113 having an EUR of 736 MMcf from the open perfs, of which 283 MMcf were produced thru 12/31/10. The #2 is shown to have an EUR of 1009 MMcf, assuming 3 -stage compression (now available), of which 768 MMcf had produced thru 12/31/10. The Middle Completion of the #9 is given an EUR of 1920 MMcf, of which 1479 MMcf had produced thru 12/31/10—this interval is now commingled with the Lower Completion, which is shown to have an EUR of 576 MMcf, of which 442 MMcf were produced thru 12/31 /10. The commingled Lower (Tyonek) and Lower Middle (Beluga) completions in the #11 are shown to have an EUR of 767 MMcf by the P/Z plot, of which 381.8 MMcf were produced thru 12/31/10. The recompletion of the NCU #I B in June 2006 provided additional pressure information of some of the Upper Tyonek Carya sands that have been producing in the #2 well. This pressure data from the tests indicates that there is no depletion of these zones in the No. 1B from the No. 2 production. In particular, the Carya 2-1.1, 2-1.2, and 2-2.1 are commingled in the #2 and had an initial SIBHP at -2285' TVDss of 1025 psig. The comparable zones in the #113, commingled 2-2.1 and 2-2.2 and the 2-1.2 had bottom -hole SIP's estimated at 1045 and 1040 psig at datum of -2484' and -2272' TVDss, both are close to the original pressure in #2 and much higher than the then most recent SIBHP's of 293 psig at -2285'. This indicates that there is a geological barrier and no communication between the two well bores. POOL PRODUCTION ALLOCATION FACTORS The production from NCU 1 B, 2, 9, and 11 is metered several times and allocated back to each well on the basis of these meters. Each of the three wells has an individual separator into which the well flows, eliminating any free water from the flow stream, then immediately downstream of the separators, each well is individually metered. The flow from the three wells may be combined at this point and then compressed before going thru the glycol dehydration system. (Booster compression has been added, so the lower pressured wells can be selectively compressed before going to the main compressor). After dehydration, the combined flow from these three wells is metered again before going into the gathering system. The gathering system takes the gas to the CIGGS Meter 6103/8103 where it is joined by the flow from NCU #3 upstream of the sales meter. It is metered before being commingled into flow going into the Marathon -operated CIGGS pipeline system. The total sales volume through this meter is allocated back to each well proportionally based on the individual well meter volume divided by the sum of all the wells meters' volumes minus lease -use gas, where lease -use (fuel) gas is allocated proportionately to each well at a facility. RESERVOIR DEVELOPMENT AND DEPLETION PLANS NCU 1B—This well produced very little gas in 2010, due to lack of market and the fact that the well produces some water and sand. In October 2008 a slick -line baler was run to check for sand fill and cleanout the tubing, as the well had been producing some sand. It was discovered that the well had significant sand fill, and in fact, the well was left with fill in the tubing at 2660', which left only the top production sliding sleeve open—thus, only the Carya 2-1.2 perfs at 2307-2370' are open and capable of production. In October 2010, the well was cleaned out with coiled tubing, the plug isolating the Carya 2-4 and 2-5 perfs was pulled, the sliding sleeves for the Carya 2-1 and 2-2 sands were closed, and the well was treated with the Weatherford SandAid chemical in KCl water. The well was being "cleaned up" after the treatment as the year ended and produced to sales only 3 days during the year, all in December. NCU #2—This well has produced with a booster compressor, giving it 3 stages of compression, but at this point is hasn't increased the rate significantly. It has (as of 12/31/10) produced 765 MMcf of the 1009 MMcf EUR and was producing at about 214 mcfpd at 115 psi in September 2010. No additional development is anticipated in this wellbore, as the only remaining apparently productive sands are behind two strings of casing in #2 and are available in the #9 well bore. However, the reservoirs in this well are being investigated for gas storage. An Storage Injection Order for the well, SIO -8, was approved by the AOGCC. NCU #9—On October 29, 2008, the Middle Completion (the original producing interval --see NCU 9 Wellbore Configuration attached) was opened to be commingled with the Lower Completion. The commingled completions produced an average of 876 mcfpd at 140 psi in September 2010. The Upper Completion will be opened and commingled with the Lower and Middle completions when pressures equalize, by opening the sliding sleeve isolating those perfs. Following the 2006 recompletion workover, this well bore still has 8 potential Beluga Tsuga 2-5 and 2-6 sands between 668' and 1054' that have apparent gas production potential. These sands were not completed at the time of the 2006 recompletion workover for 2 reasons: 1) the large pressure differential expected between these shallow sands and the deeper ones, and 2) the cement bond log indicates a top of cement at 840', so remedial cementing will be required for the shallower sand completions. Thus, at least one more recompletion workover is expected in the life of this well bore. NCU #11—This well has 2 additional shallower (Beluga) completions, which will be opened selectively and produced as needed to meet market demand. Eventually, it is expected that all 4 completions will be commingled and produced together until the well depletes or until completions make significant water, then the sleeves will be closed to shut off the water. This well averaged 1230 mcfpd at 150 psi in December 2010. Depending upon market demand and storage development, a shallow development well on the 1-2-9 pad may be drilled to recover the shallower reserves in the #9 well, both those in the Upper Completion and the shallower undeveloped sands. This would facilitate the use of the very good quality Middle Completion reservoirs for storage and would eliminate the need for an expensive recompletion workover to access the shallowest reserves. Beyond the above mentioned development, no additional development of either Pool is anticipated, as the Pools (and PA's) are now outlined. RESERVOIR PRESSURE MAP AT DATUM Because each well had its individual reservoirs, a reservoir pressure map at datum seems to be irrelevant. However, now that there are some common sands open in the #1B, #2, and #11 it may have more relevance, although the sands are apparently not continuous between wells. Attached is a pressure maps of the Nicolai Creek --South Undesignated Pool and the Nicolai Creek—Beluga Pool, showing initial and current pressures at the several pertinent subsea Data. Ed Jones (11/29/2011) )# j, \ !\/m� )#Pti - \� : : 0 L LJ - °■!f \ / - - \ § w f :, t2)®2B - _ $■®�} \ 4 - \ § 2 �_ LLJ \ \ \ \ &®a - U) °j{\E \ \ o w- \ LLI 0 ~ ` § \ \ \ ) \ \ \ \ \ \ \ \ \ } \ \ \\ t . \ \ \ \ \ \ \ k/\\z �� (t 16 \ \ ,®) ) ) ) Z5 s ]!/ : : - f : �O 61 \ w § w):77»)®)0 M - \\ /\� \\a. eCD _/>16 16 o w Ii}ƒ - \ UJ / \ \ \ \ } \ \ \ \ \ / \ k/\\z �� NICOLAI CREEK FIELD SOUTH Undesignated & BELUGA POOLS (SOUTH, WEST, & BELUGA PA's) <- Aurora Gas, LLC WELL NAME: NICOLAI CREEK UNIT !1113 FIELD: NICOLAI CREEK COUNTY, STATE: KENAI PEN. BOR.(WEST SIDE OF COOK INI RESERVOIR: COMMINGLED CARYA 2-1.2 TO 2-3 (2307-2E ' Wichert-Aziz correction for contaminants, if any WELLHEAD TEMP, °F: 40.0 SOUR GAS MOLE % BOTTOMHOLE TEMP, °F: _ 80.0 Nz 3.29 WET GAS GRAVITY: 0.572 CO, 0.30 TVD, FEET: 2,476 _ HzS 0.00 COND. cORR? (Y/N): N _ Corrected` Tc, °R: _ 340.81 Corrected' Pc, Psia _ 667.76 6/6/2006 1,038 1,102 0.8755 1,400 ; 0 n 1,200 1,000 m 800 m a N a = 600 m 400 200 Ryder Scott —r _ Reservoir ALASKA Solutions - -- (Public) _ (Protected) Least Squares Mean Fit Results Y -Intercept, BHP/z 699 OGIP, MMCF 830 EUR, MMCF _ _ 736 Recovery Factor 0.8871 BHPlz A Abandonment 79 0 100 200 300 400 500 600 700 800 900 Cumulative Production, MMcf POINT NUMBER DATE BHP/Z, CUM PROD, LSMF (Automatic) (Optional) SITP, Psia BHP, Psia Z Psia MMcf Include? (Y/N) 1 6/6/2006 1,038 1,102 0.8755 1,258 0 n 2 _ 2/10/2007 575 608, 0.9268 656 95 y 3 5/19/2007 _ _515 544 0.9341 583_ _ 159 y 4 6/12/2005 535 565 0.9317 607 1754 Y 5 8/6/2007 363 383 0.9530 402 225 n 6 _ _ 9/12/2007 438 0.9465 463 226 y 7 9/12/20071 392. 413 0.9494 435 226 n 8 12/1/2007' 315, 332 0.9591 346 256 n 9 5/29/2008 345 364 0.9554 381 261 Y 10 5/21/2009 328 346 0.9574 361 282 Y 11 _ 8/15/2010 335 353 0.9566 370 290 _ Y 12 _ 10/15/2010 535 565 0.9317 607 290 Y 13 2/4/2011 375 396' 0.9515 416 420 y Point 3 is still building. Point 5 is from SPIDR and still building _ Water in well bore? Point 6 is from bhp survey --however, sand in tubing above lower perfs Point 7 is from surface pressure at the time of the BHP survey for Point 6. Water in well bore? These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. NAME: NICOLAI FIELD: NICOLAI BOTTOMHOLE TEMP, °F: 77.0 1,400 1,200 1,000 a 800 a N a m 600 400 200 0 0 POINT NUMBER 1.06 Factor tyaer 6cott F Reservoir --?33 Solutions 1,016 1,073 0.8721 (Public) 0.8736 Protected) 0.8734 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 200 DATE 1112112003 11/22/2003 _11/22/2003 2/11/2004 6/15!2004 400 600 800 Cumulative Production, MMcf Psia I BHP, Psia Z •LSMF Data oExd. Data •EUR=1,009 •OGIP=1,058 1,016 1,073 0.8721 1,002 1,058 0.8736 1,004 1,060 0.8734 766 807 0.9004 555 5840.9264 _ n 1,214 2 N 896 142 y 630 267 0 680 270 y 427 461 n 438 470 n 0.9595 328 624 Y O 4/30/2007 8/11/2007 5/29/2008 1/31/2009 _ 295 287 124 255 _ 310 301 130 268 0.9602 0.9613 0.9832 0.9655 323 313 132 277 630 Y 647 Y 712 n 729 Y O 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 200 DATE 1112112003 11/22/2003 _11/22/2003 2/11/2004 6/15!2004 400 600 800 Cumulative Production, MMcf Psia I BHP, Psia Z CUM PROD, MMcf 1,016 1,073 0.8721 1,002 1,058 0.8736 1,004 1,060 0.8734 766 807 0.9004 555 5840.9264 _ 7/15/2004 5951 626 0.9213] 12/31/2004 385 404 0.9483 4/30/2005 395 415 0.9470 These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product 1,000 1,200 BHP/Z, Psia CUM PROD, MMcf LSMF Include? (YIN 472 y 244 554 n 1,230 0 n 1,211 2 n 1,214 2 N 896 142 y 630 267 N 680 270 y 427 461 n 438 470 n These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product 7/16/2005 2/17/2006 9/14/2006 1_0/3/2006 12!31/2006 415 225 168 _195 240 436 236 _ 176 204 252 0.9444 0.9695 0.9772 0.9736 0.9675 462 472 y 244 554 n 180 609 n 210 609 N 260 624 N 1/18/2007 255 268 0.9655 277 624 N 2/4/2007 _ 275 0.9629 300 624 n 3/8/2007' 300 _ _289 315 0.9595 328 624 Y 4/30/2007 8/11/2007 5/29/2008 1/31/2009 _ 295 287 124 255 _ 310 301 130 268 0.9602 0.9613 0.9832 0.9655 323 313 132 277 630 Y 647 Y 712 n 729 Y These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product COUNTY, STATE: T11N, R12W SM, Kenai RESERVOIR: Beluga 1320-1447' (MID Wirhert-AA7 cnrrectinn for contaminants. if anv WELLHEAD TEMP, *F: 40.0 SOUR GAS MOLE % BOTTOMHOLE TEMP, OF: 68.0 Ni 0.89 WET GAS GRAVITY: 0.5633 CO2 0.35 TVD, FEET: 1,364 HS 0.00 CONO. CORR? (YIN): N Corrected` Tc, °R: 343.86 Corrected* Pc, Psia: 672.10 800 700 600 500 a a ti 400 'a m 300 200 100 0 Cyder Scott'J Reservoir Solutions (Public)1 MMCF 0 500 1.000 1,500 2,000 2,500 Cumulative Production, MMcf POINT NUMBER (Automatic) DATEBHP/Z, (Optional) SITP, Psia •LSMF0&ia oFxq. Dela DEUR=1,920 •OGIP=2,031 Z Psia CUM PROD, MMcf LSMF Include? (Y/N) 1 2 9I2212003 11/20/2003 667 677 688 0.9086 0.9072 745' 759 0 0 n y 3 2/11/2004 O 605 0.91791 659 108 y 4 6/18/2004 515 531 0.92751 O � 10 y 5 12/31/2004 O _ 417 0.9427 4431 666 0 500 1.000 1,500 2,000 2,500 Cumulative Production, MMcf POINT NUMBER (Automatic) DATEBHP/Z, (Optional) SITP, Psia BHP, Psia Z Psia CUM PROD, MMcf LSMF Include? (Y/N) 1 2 9I2212003 11/20/2003 667 677 688 0.9086 0.9072 745' 759 0 0 n y 3 2/11/2004 _ 5861 605 0.91791 659 108 y 4 6/18/2004 515 531 0.92751 5731 10 y 5 12/31/2004 405 _ 417 0.9427 4431 666 n 6 4/30/2005 420 _ 433 0.9406 460T 680 n 7 7/16/2005 435 448 0.9385 478 682 Y 8 2/17/2006 325 335 0.9538 351 864 Y 9 9/12/2006 173 179 0.9752 183 1,068 n 10 5/21/2009 227 _ 0.9686 234 1,228 n 11 9/2/2009 _220 255 263 0.9637 273 1,2281 Y 12 13 7/4/2010 9/21/2010 235 205 242 211 0.9665 0.9708 _ _ 250 217 1,392 1,453 Y y Point 1 is bhp from open -hole MDT. Point 2 is surface pressure measured by testers before 4 -point test. Poiint 3 is surface pressure from crystal pressure recorder. Point 4 is gauge pressure. Points 5, 6, and 7 is tree gauge pressure after long -tens SI (4/1/05) Point 8 is tree gauge pressure after 28 hr SI Point 9 is short -time shut in Just before recompletion—not likely built up to static. These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. WELL NAME: NICOLAI CREEK UNIT #9 Ryder Scott 11 FIELD: NICOLAI CREEK Reservoir ti COUNTY, STATE: KENAI PEN. BOR., (WEST SIDE OF COOK INLET), ALASKA Solutions t-i(y�■ _ RESERVOIR: BELUGA (TSUGA 2-7 & 2-8) PERFS AT 1552-1904 (LOWER) (Public) rt -Aziz correction for contaminants. if am (Protected) 1,000 900 800 700 A N a N 500 a x ut 400 300 200 100 0 0 IP, °F: 74.0 ►VITY: 0.562 FEET: 1,728 (Y/N): N rc,=R: 343.56 Factor 100 200 300 400 500 600 700 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) I SITP, Psia I BHP, Psia •LSMF Da oEzU. Data •EUR=576 •OGIP=603 BHP/Z, Psia CUM PROD, MMcf LSMF Include? (YIN) 1 9/26/2006 650 676 0.9139 739 2 y 2 --� 2/10/2007 435 452 O 480 94 n 3 5/1/2007 O O O 563 109 n 4 7/16/2007 475 493 0.9362 527 159 y 5 8/11/2007 637 0.9186 693 _ 163 n 6 9/25/2003 810 0.8981 902 0 n 7 8/11/2007 389 _ 404 0.9475 100 200 300 400 500 600 700 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) I SITP, Psia I BHP, Psia Z BHP/Z, Psia CUM PROD, MMcf LSMF Include? (YIN) 1 9/26/2006 650 676 0.9139 739 2 y 2 --� 2/10/2007 435 452 0.9414 480 94 n 3 5/1/2007 505 525 0.9323 563 109 n 4 7/16/2007 475 493 0.9362 527 159 y 5 8/11/2007 637 0.9186 693 _ 163 n 6 9/25/2003 810 0.8981 902 0 n 7 8/11/2007 389 _ 404 0.9475 426 163 n 8 11/6/2007 385 400 0.9480 422 208 n 9 5/29/2008 351 365 0.9525 383 271 Y 10 11 10/13/2008 517/2009 _ 260 215 270 223 0.9647 0.9707 280 230 325 385 Y n 12 5/21/2009 220 228 0.9701 235 385 n 13 9/2/2009 255 265 0.9653 274 385 Y 14 7/4/2010 235 24_4 0.9680 252 413 Y 15 9/21/2010 205 213 0.9721 219 434 Y Point 9 is SPIDR reading after 7 day St _ Point 10 is 2-3 day SITP Point 1 is SITP of initial test These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. WELL NAME: NICOLAI CREEK UNI FIELD: NICOLAI CREEK COUNTY, STATE: KENAI PENINSULA E RESERVOIR: L. Tsuga 2-7 & 2-8 + ( Ulf;.d _ A�rs......n..fi—f—�nnfamimmnf if Anv WELLHEAD TEMP, °F: 50.0 SOUR GAS MOLE % BOTTOMHOLE TEMP, °F: 87.0 IN1.00 LSMF Include? (YM) WET GAS GRAVITY: 0.562 CO= 0.00 TVD, FEET: 2,049 HS 0.00 COND. GVKK7(YIN): N Corrected" Tc, °R: 344.25 Corrected° Pc, Psia: 671.89 1,200 1,000 800 A p o. 600 o. x m 400 200 Reservoir Solutions 5.0 (Public) MMCF IL 0.9267 0 100 200 300 400 500 600 700 800 900 Cumulative Production, MMct POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z BHPlZ, Psia CUM PROD, MMcf LSMF Include? (YM) 1 2 3 4 _ 10/6/2009 9/1/2010 10/11/2010 5/31/2011 881 585 595 385 923 612 6220.9264 402 0.8946 0.9276 0.9515 1,032 659 672 422 0 282 293 492. Y Y Y Y These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product.