ES DEssign

ESPfinal reportsteve23.doc

___________________________________________ ESP FEASIBILITY STUDY FOR KUROVDAG FIELD Prepared by: Max Bough (IPM) Revised by: Luis M. Sandoval N.( IPM )

Max Bough/ Luis M. Sandoval

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ESPfinal reportsteve23.doc

CONTENT

I. II. III. IV. V. VI. VII. VIII. IX. X. XI.

HISTORY ESP JUSTIFICATION METHODOLOGY (ESP CANDIDATE SELECTION) ADDITIONAL CONSIDERATIONS CONCERNS RISKS RESULTS AND RECOMMENDATIONS DESIGNS COST ESTIMATES INSTALLATION PROGRAM AND GUIDELINES ATACHTMENTS

Max Bough/ Luis M. Sandoval

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ESPfinal reportsteve23.doc

I. HISTORY The Kurovdag field had some ESP installations in the past (around 20-30 in the 90’s) with about 13-14 wells as recently as 2000. Shirvan’s approach was to pump high water -cut high volume wells. According to interviewed field personnel, there were several probable causes for cancellation of the ESP program. The ESP program was discontinued as a result of the following probable reasons: poor management decisions (such as imprudent water handling that became expensive), company’s financial problems at the time and internal politics (most likely cause). The company providing ESP services at the time for Shirvan was Azneft, which charged around $35 per installation on daily basis. The service covered ESP systems completely: completion design, servicing, troubleshooting were all handled by Azneft at its expense. Virtually all ESP-associated risk was handled by this service company. Recently, Schlumberger held a business meeting with Azneft regarding future possibilities of using their services. Given certain assurances, they are willing to work under similar schemes as before.

II. ESP JUSTIFICATION Having reviewed the producing potential of the active wells in the field, current installations (Rod Pumps) and previous ESP experience, the Schlumberger team concluded that only introduction of an alternative artificial lift technology in the field will drastically improve field’s production. The current rod pump systems are not well suited for the application: they have a high failure rate due to emulsion/sand problems and are operated under poor engineering practices. All of these results into intensive maintenance, high operational costs and, obviously, in a limited production on beam pupm. A more flexible reliable artificial lift system is needed to improve efficiency, profitability and production in the field. Such systems could be ESPs, PCPs and potentially jet pumps.

III. METHODOLOGY (ESP CANDIDATE SELECTION) Extensive criteria have been applied to producing wells to come up with the best 10 candidates (See Table 1 for Criteria). First, all active wells were scanned for current production, water cut, and dynamic fluid levels, which resulted into the pool of 59 wells. Second, the wells were broken down into 3 production tiers and IPR curves were constructed for the first 16 wells. The results indicated that wells with lesser production, higher watercut and lower pressures do not appear very attractive economically, so the first 16 were retained for further study. Third, the wells were re-ranked based on their PI and minimum expectation of incremental oil at Pwf of 500 psi (3.4 MPa) (roughly equivalent to 400 m of fluid column above the upper perf). The top 10 candidates were screened with DCS using geological and reservoir criteria. Finally, all 10 were reviewed with the field geologists and engineers for wellbore conditions. Table 2 and Figure 1 through 3 present the results of the study. Note that the geological and reservoir uncertainties were mitigated in all calculations. In cases where PI computations were affected by lack of data or a range of uncertainties, the most conservative guesses were used to eliminate the risk of overestimation. Similarly, reserve estimates are presented rather conservatively. In addition, uphole potential was often minimized, and in reality should be a higher number.

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IV. ADDITIONAL CONSIDERATIONS There are several additional considerations that will be addressed during further development of the ESP project. It is suspected that the most wells in the field have a rather significant skin caused by either drilling in the past or current operating practices. While the presented here results reflect the current operating conditions of the wells, much better deliverability could be expected if the skin damage is remove d. Therefore, the IPM team is actively searching for ways to address this issue (i.e. organic solvents or other products which may be provided by local chemical companies). Finding a solution may yield significant economic benefits for the project. Wellbore cleanout is another issue being studied by the IPM team. It has been observed that some of the perforations in the field were sanded off with the consequent re-completion in the upper zones, avoiding attempts to bail the produced sand. A practice of bailing the produced sand and cleaning the perfs properly may prove an economic project of its own and may also improve expected deliverability of the wells. Cement condition (mechanic & hydraulic ) behind the casing is extremely critical to achieve incremental oil production without an iflux of water, which may be caused by improper cement isolation and channelling from adjacent zones. In additon, appropriate cement isolation will minimize problems with the ESP downhole equipment and extend the lifetime of the installation. Precise knowledge of wellbore configuration in terms of real casing ID clearance is a big issue . Casing collapse and non-standard tubular installation (irregular csg design) are quite common problems in the Kurovdag wells . F or that reason dummy runs must be done before any ESP installation. Understanding the flowline configuration along with the appropriate well test data before and after ESP installation are crucial for a good well performance assessment and confirmation of the incremental value incorporated by this type of artificial lift system. Knowing that some formations in Kurovdag Field are susceptible to sand production even with beam pump system, it is recommended to control the speed of the ESP (variable speed drives). This way the inflow of the well could be reduced and the amount of fines controlled to prevent premature problems for ESP subsurface equipment. Utilization of down hole sensors, such as pressure and temperature will be needed to verify data supplied by the Echometer. Such sensors will allow to confirm well P Is. With introduction of ESP lift system, paraffin deposition should slow down along the tubing string due to higher temperatures and flowrates and move to the surface facilities. This issue has to be addressed in more detail with possible chemical treatment and adjustments at the surface.

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V. CONCERNS There was some disagreement with the Shirvan field people. Field geologists insist than none of the studied wells would benefit from ESP lift. According to them, any additional drawdown created by ESPs would change the producing regime of the formation, bringing in a lot of sand into the wellbore and killing the well. In addition, several other reasons were brought up such as imprudent usage of reserves with ESP lift (appare ntly ESP are supposed to decrease the final recovery!!!) and low permeability of the aforementioned wells (those are the highest PIs in the field!!!). Instead, they offered a list of wells they want to put on ESPs, which incidentally have 90% and above watercut (in most cases producing from the same sands as chosen by IPM). When asked whether these high watercut wells would have any of the mentioned sand problems, they simply propose staying a sufficient amount of distance from the perfs to let the sand settle. Incidentally, an ESP specialist who worked in Kurovdag extensively in the past says that only few formations gave his ESPs any sand-associated problems such as Apsherons (PS series was said to be manageable). Ultimately, this sand producing theory has to be studied more carefully to have some kind of technical/empirical answer to those claims. The answer just may be Shirvan’s old local mentality of delaying production and accelerating production in high water cut wells to keep them active.

VI. RISKS As it was mentioned before, a comprehensive list of criteria was applied to the studied wells trying to filter out any apparent risk associated with ESPs. Nevertheless, there are further studies needed to evaluate potential risks of the following. First is sand production. Sand theories given by Shirvan field geologist are not consistent and are not based on any hard evidence (same as with their GOR estimates). Thus, a more detailed quantitative evaluation of the sand problems involving fluid samples and review of sand production history is require d. In addition, ESP local specialists, preferably with an extensive knowledge of the Kurovdag Field, can be a useful source of experience and will help to formulate the required forward plan and mitigate known risks. Second potential risk may be presented by wellbore conditions. The discussed wells were reviewed with the field geologists and were deemed suitable. Nevertheless, a dummy run, preferably following a wellbore clean up, is recommended before running the equipment. Paraffin is another consideration worth mentioning. With introduction of ESP lift, paraffin deposition should slow down along the tubing string due to higher temperatures and flowrates and move to the surface facilities. This issue will be addressed in more detail with possible chemical treatment and adjustments at the surface. A comprehensive risk-weighted decision tree will eventually be constructed to evaluate effects of the potential risk on the expected cash flow in case of ESP installation.

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VII. RESULTS AND RECOMMENDATIONS Based on the reserve estimates, expected flowrates and other aforementioned criteria, the following wells deserve further attention and should be considered for further evaluation: 1030, 1045, 1126, 1263, 1220 and 1355. These wells have significant reserves to back up expected high PIs, which range from 8,500 to 44, 000 recoverable reservoir cubic meters (~59,000 – 300,000 stb) and significant uphole potential (See Table 2 and Figure 1 through Figure 3 for reference). Their expected incremental oil deliverability ranges from 5 to 26 tonne/d (~ 38-200 stb/d for assumed Pwf of 500 psi). These wells present a low risk investment from the reservoir and deliverability standpoint, and in the case of successful introduction of ESPs or PCPs should yield significant financial returns. The rest of the wells listed in the report (345, 751, 1181, and 1222) appear unsuitable for ESP application due to a series of reasons, such as a risk of depletion, watering out or limited drainage area (See Table 2 for details). These wells are still decent producers and should be considered for low-cost optimisation with the current lift equipment or other low-cost alternatives. Note, that some of them, specifically 751 and 1181, have decent uphole potential and could be considered for ESP lift if recompleted in the above zones.

VIII. DESIGNS Preliminary designs were generated for each of the selected wells to identify the type of downhole and surface equipment required (See attached designs). Note, that at this point there are ranges of uncertainties for such input variables as GOR, gas rates and PI estimates. In addition, well test data have in some case are uncertain.

IX. COST ESTIMATES Table 3 summarises ESP costs for benchmarking purposes (Azerbaijan, Russia n and USA made ESPs are compared). At this point, the most attractive ESP vendor would most probably be Azneft. Because of the low cost (possibly ~$35-40/day/well), knowledge of the field and complete service that mitigates the risk for Schlumberger and the client, this company appears as the most likely choice. In addition, this company has experience putting together and running various equipment of local, Russian and Western manufacturing, that gives them extra flexibility in design of the systems. Some contractual assurances would have to be given to Azneft to solidify Shirvan’s and Schlumberger’s commitment.

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X. INSTALLATION PROGRAM AND GUIDELINES Below is the outline for ESP program w ith description and important guidelines for ESP installation in the Kurovdag Field. Prior to the job: • • • • • • •

Reconfirm input data for ESP design is accurate Perform a representative well test prior to ESP installation (to confirm Oil, Water, Gas, GOR, BSW, API, Fluid level among other parameters). This will serve as a benchmark for ESP performance. Design the most adequate E SP system according to the well potential deliberability Have a written detailed operational program, including roles and responsibilities for SLB personnel and for the Operator Obtain agreement and signatures from the corresponding parties Confirm that pulling unit or work-over rig to be used has adequate personnel, and tools to execute the job in an efficient and safe way Confirm that both production and operation people in the field are in the loop and receive additional production from the well (satellites-Production Areas-Tank Farm)

During the job: • • • • • • • • • • • • • • • •

Perfom a coordination meeting with all the personnel involved in the ESP installation Review the progr am and clarify doubts (roles & responsibilities) Confirm that all the required equipment and personnel are available at the well site Ensure the well is controlled and the required flow barriers are in place (keep control fluid in surface as a contingency) POOH existing completion configuration and monitor permanently static fluid level condition ( avoid kick of the well ). Fill out well with control fluid Do service for EPM motor and seal section then RIH ESP equipment (Temperature & Pressure sensors, motor, seal section, pump or gas separator if the last one is required ) RIH ESP equipment slowly, following manufacturer’s guidelines to protect equipment and cable Verify integrity of the ESP power cable at least every 500 m (avoid turning pipe and cable while RIH ESP). No more than three splices on the cable must be done . Hang tubing string on tubing hanger and install back pressure valve (BPV) Remove BOPs to install X-tree Install Test valve and perform X-tree test for at least 15 minutes Remove test valve Make up flow line and connect it to test separator Perfom hydraulic test on flowline an test separator Check electric conditions on surface (vent box, transformer, VSD or swithboard) Prepare surface equipment to receive fluid production (flow line, test separator, satellite. Hand radios are extremely useful! )

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• • • •

Set operating parameters on VSD or switchboard Perform quick coordination meeting just before start up ESP Start ESP pump and monitor permanently well parameters and ESP performance Execute a short test approximately six (6) hours before release work over rig or pulling unit

After the job: •

Perform a representative well test (approximately 24 hrs) to get the control fluid or dead fluid displaced by the ESP pump. The following parameters must be collected every 30 minutes to quantify the value added ( incremental production by ESP) o o o o o o o o o o o o o o o o o

ESP frequency ESP motor voltage ESP amperage ( three phases ) Down hole Pressure Down hole temperature Well head pressure Casing pressure Dynamic fluid level Separator pressure Separator temperature Fluid production Oil production Water production Gas production API gravity Gas specific gravity Water gravity

Note: Charts will be a good indication for well evaluation.

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XI ATTACHMENTS Table 1: ESP Candidate Selection Criteria Table 2: Summary for Top 10 ESP Candidates Table 3: ESP Vendors and Costs Figure 1: Reserves and Expected Incremental Oil Figure 2: Reserves and Total Expected Oil Figure 3: Reserves and Uphole Potential Attached ESP designs for 6 wells

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Table 1: ESP Candidate Selection Criteria Initial Screening Production History Productivity index ( PI ) or well reservoir fluid deliverability Water cut ( BSW ) and GOR Geology Perforation history, block details, reservoir boundaries Quality of sands, adjacent producers and production performance of sands Water contacts, water injection Reservoir OOIP estimates, Cumulative production history, illegal perfs, remaining reserves Drainage area (boundaries), water injection, w. conning Current and post production decline Uphole Potential Operations Parafin/asphaltenes production, emulsion problems, sand/fine production Verification of casing size, condition of casing, cement behind casing Wellhead and flowline conditions Tubing condition and availability Surface equipment capacity to handle additional volumes Surface facilities to perform well test, additional testing equipment Power supply system availability to be transmited to ESP motor Wellsite conditions (Access road, location) Well deviation

D/Current/ESPESPCandSteveFigures.xls

6/5/2003

Table 2: Summary for Top 10 ESP Candidates Perfs

P Csg

P Csg

Parafin

Pr Estimate

Recent FL

Mid-Perf

m

mm

Condition

Problems

Mpa

Above MP, m

(m)

oil, t/d

W, m3/d

WC, %

PS02

3115-3123

146

good

severe

17

1,552

3,119

9.6

3.2

23

PA03

PS04,05,06-09

2154-2275

152 X 127

good

no info

14

1,350

2,472

8

6.5

42

BL01

PA01 N

PS 01+PS02

2805-2978

146

good

severe

23

2,058

2,892

8.6

13.2

62

1045

BL13

PA03

PS08+PS09

2887-2990

146 X 178

good

moderate

36

flowing

2,951

15.1

5.4

24

1126

BL10

PA03

PS07+PS08

2820-3025

146 X 168

good

no info

25

1,890

2,938

9.3

3.5

25

1181

BL01

PA01 S

PS03

2869-2930

146

good

moderate

22

1,773

2,899

9.6

18.3

64

1222

BL01

PA01 N

PS02+PS03

3023-3093

146

good

severe

24

1,954

3,058

12.4

6.9

33

1263

BL13

PA03

PS09+PS10

2856-2936

140 X 146 X 168

good

no info

36

flowing

2,896

25

0.3

1

1220

BL01

PA01 N

PS 04+06

3094-3328

146

good

severe

23

2,210

3,211

24.3

0

0

1355

BL01

PA01 N

PS03+PS04

3046-3308

146

good

severe

22

1,862

3,148

11.5

4.4

26

Well

Block

PA

345

BL04

PA01 S

751

BL12

1030

Zone

Production March'03

*Expected Performance (Pwf ~ 500 psi (3.4 Mpa)) Total Liq

Total Oil

m3/d

oil, t/d

Low

Med

High

345

25

17.3

7.7

11.0

13.7

0

0

7,800

751

32

16.7

8.7

11.1

13.4

0

0

5,800

1030

56

19.3

10.7

12.0

14.1

24,600

40,400

56,000

1045

60

41.2

26.1

31.6

36.0

37,000

44,500

52,000

32,000 Huge reserve potential (up to 120,000 drained by 1045 and 1263 (360 m away). Uphole P > 100m

1126

29

19.6

10.3

22.9

32.1

44,000

55,000

66,000

18,000 Huge reserve potential (up to 100,000 in the block drained only by 1126)

1181

48

15.6

6.0

10.1

14.1

0

0

0

1222

40

24.4

12.0

14.1

16.4

5,000

7,200

9,400

1263

50

44.6

19.6

23.6

27.0

32,000

39,500

47,000

1220

33

29.3

5.0

7.9

9.6

31,000

36,500

42,000

3,500 Good reserves, low decline

1355

29

19.1

7.6

10.7

14.0

8,400

10,500

12,600

3,400 Ok reserves, little uphole potential

Well

Incr. Oil 3 Est., t/d

D/Current/ESP/ESPCandSteveFigures.xls

Uphole P.,

Remaining Rec Reserves, Rm3 Low

Med

High

Comments

Rm3 0 May be close to depletion 17,800 May be close to depletion, decent uphole sands (>50m) 4,300 Excelent current reserves, little uphole

12,500 PS 03 - bad quality, offset producers show water coming in 1181 6,800 Thin sand, limited drainage (wtr), small uphole potential 38,000 Huge reserve potential (up to 120,000 drained by 1045 and 1263 (360 m away). Uphole P > 200m

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Table 3: ESP Cost Estimates and Benchmarking

VENDOR

COST

VSD

SERVICE

(Complete System), K$

Variable Speed Drive

(supervision, repairs, troubleshooting)

REPRESENTATIVE

MANUFACTURING

NOTES

Alnas (Russia)

40 K(VSD not available)

N/A

extra

RU (Moscow, Tatarstan)

Russia

cost includes delivery

Borets (Russia)

28-30 K (35-40 w VSD)

available 2003

extra

Moscow

Russia

cost includes delivery

Reda (US)

100-150K (200K w VSD)

YES

extra $500/hr

Moscow

Oklahoma/Dubai

delivery will cost more

ESP Woodgroup (US)

$130-160K (w VSD)

YES

extra

Moscow

Dubai

delivery will cost 20-30% more

Weatherford (US)

150-200 K (w VSD)

YES

extra

Austria

Dubai

delivery will cost more

CentrLift (US)

150-200 K (w VSD)

YES

extra

Baku

Dubai

delivery will cost more

Azneft ESP (Azerbaijan)

$35/well/day*

N/A

included

Baku

Baku

local cost, also can equipment others

Reserves and Initial Increments (ESP Candidates) 50

60,000

50,000

Reserves, Rm3

40,000 30 30,000 20 20,000

Initial Incremental Oil Rates, tonne/d

40

10 10,000

0

345

751

1030

1045

1126

1181

1222

1263

1220

1355

Wells Reserves, Rm3

Initial Incremental Oil Rates, tonne/d

Figure 1: Reserves and Expected Minimum Incremental Oil Rates

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Reserves and Total Oil Rates Expected (ESP Candidates) 50

60,000

50,000

Reserves, Rm3

40,000 30 30,000 20 20,000

Initial Total Oil Rates, tonne/d

40

10 10,000

0

345

751

1030

1045

1126

1181

1222

1263

1220

1355

Wells Reserves, Rm3

Initial Total Oil Rates, tonne/d

Figure 2: Reserves and Total Minimum Expected Oil Rates

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Reserves and Uphole Potential (ESP Candidates) 90,000

80,000

70,000

Reserves, Rm3

60,000

50,000

40,000

30,000

20,000

10,000

345

751

1030

1045

1126

1181

1222

1263

1220

1355

Wells Reserves, Rm3

Uphole Potential, Rm3

Figure 3: Reserves and Uphole Potential Combined

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ESP DESIGNS FOR THE BEST SIX CANDIDATES (Curves Attached) WELL 1355 GENERAL DESCRIPTION

WELLBORE DATA

Company Name: Schlumberger Well Name: 1355 Field Name: Kurovdag Reservoir Name: PS Analyst: Eduardo Escobar D. Calculation Type: Rigorous Design Location: Comments: Date: 06/03/2003

PUMP DATA 1 Manufacturer: Series: 338 Model: A400

Rough. in

SEAL DATA OD Bottom MD No. in ft ft

Wt Top MD lb/ft

ID in

6.50

2.441

2.875

Casing 1 5.500 15.50 0.0006500 10800.00 0.00 Pump Depth, ft: 9600.00 Top of Perfs. or Datum Pt. (MD), ft: 10051.00 Reservoir Temperature, °F: 150.0 Wellhead Temperature, °F: 70.0

Reda

0

Viscosity Correction Factors User Entered Rate: 1.000 No Head: 1.000 No Power: 1.000 No Efficiency: 1.000 Design 624 Stages Total Dynamic Head (TDH), ft: 6384.71 6427.15 Surface Rate (O+W), Bbl/D: 300.00 301.04 Avg. Pump Rate (O+G+W), Bbl/D: N/A 345.35 Pump Intake Pressure, psig: 1171.0 1163.1 Operating Power, HP: N/A 40.9 Min. Efficiency, %: N/A 33.6 Pump Derating Derating Factor for Rate, %: 92.0 Derating Factor for Head, %: 92.0 Derating Factor for Power, %: 115.0 Housing Data Hsg. # Hsg. Type Length, ft # of Stages 100 FL 14.80 208 100 FL 14.80 208 100 FL 14.80 208 Total 300 44.40 624 Blank Stages Input: 0 Net Stages in Pump: 62

325 HL PF SB

Bearing Cap., lb: 3144.5 Operating Thrust Load, lb: 791.1 Maximum Thrust Load, lb: 1190.2 Power Consumption, HP: 0.4

4.950

CABLE DATA

Manufacturer: Reda Series: 375 Type: 87 - Double

Minimum Recommended Rate, Bbl/D: 158.84** Maximum Recommended Rate, Bbl/D: 397.11** Rate at Peak Efficiency, Bbl/D: 208.00** Power at Peak Efficiency, HP: 23.5** Frequency, Hz: 52.0 ** = Corrected for Frequency & Viscosity

Reda

HTM HL Tubing 1 0.0006500 9600.00

MOTOR DATA

Number of Stages, : 624 Stages with Free Gas: 624 Additional Stages due to Gas:

Manufacturer: Series: 325-375 Bearing Type: Chamber Selection:

Name Plate Power, HP: Plate Frequency, Hz: 60 Name Plate Voltage, Volts: Plate Current, Amps: 37.0 Adjust for Motor Slip:Yes 29.3 Design Frequency, Hz: Operating Voltage, Volts: Operating Motor Load, HP: Operating Power Factor, frac: (@ Design Frequency) Operating Motor Load, : Operating Efficiency, %: Operating Speed, RPM: Velocity, ft/sec: 0.342

76.5

Name

1500.00

Name

Manufacturer: Reda Type: Redalead Size: 4 Cu Shape: Round Conductor Type: Solid Max. Cond. Temp., °F: 400.0 Cable Length, ft: 9700.00

Operating Current,

Solve for: Surface Voltage Electric Cost, $/kWH: 0.00

Amps:

52.0 1300.00 43.5 0.611 65.65 74.82 3021

Design Freq.

Fluid

Well Fluid Temperature, °F: 146.4 Speed Increase Heating, °F: 0.0 Skin Temperature Rise, °F: 42.0 Harmonic Heating due to VSD, °F: 4.3 Avg. Winding Temp. Rise over Skin, °F: 25.0 Total Winding Temp., °F: 213.4 If Sine Wave Filter is used in VSD operation, Harmonic Heating is zero. Catalog

Actual

Total Stages 624 624 Slip Stages 0 0 Total Dynamic Head (TDH), ft 6427.15 6381.87 Surface Rate (O+W), Bbl/D 301.04 Avg. Pump Rate (O+G+W), Bbl/D 343.95 Pump Intake Pressure, psig 1163.1 Operating Power, HP 40.9 40.9 Min. Efficiency, % 33.6 33.8 Operating Speed, RPM 3033

Volts

299.82 345.35

Volts

1172.3

Volts

3021

Frequency, Hz 52 Conductor Temp., °F 156.3 Max. Allowable Amps, Amps 147.9 Amperage, Amps 29.3 Kilovolt Amper, KVA 73.6 Kilowatts, KW 45.0 Kilowatts, $/mo 0 Surface Voltage, Volts 1452.3 Voltage Drop @ 68.0 °F, Volts 129.5 Voltage Drop @ 150.0 °F BHT, 152.3 Kilowatt Loss, KW 4.7 Cost of Voltage Loss, $/mo 0 Required Motor Voltage, Volts 1300.0 Downhole Voltage at Motor, 1300.0 In-rush Motor Voltage Drop, 609.0 Motor Startup Voltage, Volts 843.2 Startup/Operating Ratio, ratio 0.6

WELL 1220 GENERAL DESCRIPTION

WELLBORE DATA

Company Name: Schlumberger Well Name: 1220 Field Name: Kurovdag Reservoir Name: PS 04/05 Analyst: Eduardo Escobar D. Calculation Type: Rigorous Design Location: Comments: Date: 06/03/2003

OD

Wt Top MD in

SEAL DATA ID

Rough.

Bottom MD

No. ft

in ft

lb/ft

in

2.875

6.50

2.441

Tubing 1 0.0006500 9700.00

Casing 1 5.500 0.0006500 11000.00 0.00

15.50

Manufacturer: Reda Series: 325-375 Bearing Type: Chamber Selection: HTM HL

Bearing Cap., lb: 3285.9 Operating Thrust Load, lb: 876.1 Maximum Thrust Load, lb: 1301.6 Power Consumption, HP: 0.4

4.950

Pump Depth, ft: 9700.00 Top of Perfs. or Datum Pt. (MD), ft: 10210.00 Reservoir Temperature, °F: 150.0 Wellhead Temperature, °F: 70.0 PUMP DATA 1 Manufacturer: Series: Model:

MOTOR DATA Reda 338 A400

Manufacturer: Series: Type:

Minimum Recommended Rate, Bbl/D: 167.21** Maximum Recommended Rate, Bbl/D: 418.02** Rate at Peak Efficiency, Bbl/D: 363.00** Power at Peak Efficiency, HP: 49.1** Frequency, Hz: 55.0 Number of Stages, : 624 Stages with Free Gas: 624 Additional Stages due to Gas:

0

Viscosity Correction Factors User Entered

Design

Rate: 1.000 Head: 1.000 Power: 1.000 Efficiency: 1.000 624 Stages

No No No

Total Dynamic Head (TDH), ft: 7469.33 7489.49 Surface Rate (O+W), Bbl/D: 300.00 300.52 Avg. Pump Rate (O+G+W), Bbl/D: N/A 351.35 Pump Intake Pressure, psig: 966.3 963.2 Operating Power, HP: N/A 46.5 Min. Efficiency, %: N/A 33.4 Pump Derating Derating Factor for Rate, %: Derating Factor for Head, %: Derating Factor for Power, %: Housing Data Hsg. # Hsg. Type 100 FL 100 FL 100 FL Total 300 Blank Stages Input: Net Stages in Pump:

92.0 92.0 115.0

Length, ft 14.80 14.80 14.80

# of 208 208 208

44.40 0 624

624

325 HL PF SB

CABLE DATA Reda 375 87 - Double

Name Plate Power, HP: Plate Frequency, Hz: 60 Name Plate Voltage, Volts: Plate Current, Amps: 51.5 Adjust for Motor Slip:Yes 45.2 Design Frequency, Hz: Operating Voltage, Volts: Operating Motor Load, HP: Operating Power Factor, frac: (@ Design Frequency) Operating Motor Load, : Operating Efficiency, %: Operating Speed, RPM: Velocity, ft/sec: 0.340

67.5

Name

990.00

Name

Manufacturer: Reda Type: Redalead Size: 2 Cu Shape: Round Conductor Type: Solid Max. Cond. Temp., °F: 400.0 Cable Length, ft: 9800.00

Operating Current,

Solve for: Surface Voltage Electric Cost, $/kWH: 0.00

Amps:

55.0 907.50 49.1 0.664 79.36 77.29 3181

Design Freq.

Fluid

Well Fluid Temperature, °F: 146.0 Speed Increase Heating, °F: 0.0 Skin Temperature Rise, °F: 51.8 Harmonic Heating due to VSD, °F: 4.3 Avg. Winding Temp. Rise over Skin, °F: 25.0 Total Winding Temp., °F: 222.8 If Sine Wave Filter is used in VSD operation, Harmonic Heating is zero. Catalog Total Stages Slip Stages

Actual 624 0

Volts 624 0

Volts Volts

Frequency, Hz 55 Conductor Temp., °F 157.8 Max. Allowable Amps, Amps 209.3 Amperage, Amps 45.2 Kilovolt Amper, KVA 82.7 Kilowatts, KW 54.9 Kilowatts, $/mo 0 Surface Voltage, Volts 1056.7 Voltage Drop @ 68.0 °F, Volts 127.0 Voltage Drop @ 150.0 °F BHT, 149.2 Kilowatt Loss, KW 7.7 Cost of Voltage Loss, $/mo 0 Required Motor Voltage, Volts 907.5 Downhole Voltage at Motor, 907.5 In-rush Motor Voltage Drop, 597.0 Motor Startup Voltage, Volts 459.8 Startup/Operating Ratio, ratio 0.5

WELL 1126 GENERAL DESCRIPTION

WELLBORE DATA

Company Name: Schlumberger Well Name: 1126 Field Name: Kurovdag Reservoir Name: PS 07/08 Analyst: Eduardo Escobar D. Calculation Type: Rigorous Design Location: Comments: AN550 Date: 06/03/2003

OD

Wt Top MD in

SEAL DATA ID

Rough.

Bottom MD

No. ft

in ft

lb/ft

in

2.875

6.50

2.441

Tubing 1 0.0006500 8800.00

Casing 1 5.500 0.0006500 10000.00 0.00

15.50

Manufacturer: Reda Series: 325-375 Bearing Type: Chamber Selection: HTM HL

325 HL PF SB

Bearing Cap., lb: 3285.9 Maximum Thrust Load, lb: 3001.0 Power Consumption, HP: 0.6

4.950

Pump Depth, ft: 8800.00 Top of Perfs. or Datum Pt. (MD), ft: 9282.00 Reservoir Temperature, °F: 150.0 Wellhead Temperature, °F: 70.0 Tubing Outflow Correlation: Brown (1963) PUMP DATA 1 Manufacturer: Series: Model:

MOTOR DATA Reda 338 AN550

Manufacturer: Series: Type:

Minimum Recommended Rate, Bbl/D: 301.50** Maximum Recommended Rate, Bbl/D: 527.62** Rate at Peak Efficiency, Bbl/D: 532.95** Power at Peak Efficiency, HP: 72.1** Frequency, Hz: 57.0 Number of Stages, : 652 Stages with Free Gas: 652 Additional Stages due to Gas: 0 Viscosity Correction Factors User Entered Rate: 1.000 No Head: 1.000 No Power: 1.000 No Efficiency: 1.000 Design 652 Stages Total Dynamic Head (TDH), ft: 7439.40 7515.67 Surface Rate (O+W), Bbl/D: 350.00 352.21 Avg. Pump Rate (O+G+W), Bbl/D: N/A 389.16 Pump Intake Pressure, psig: 780.6 768.1 Operating Power, HP: N/A 75.3 Min. Efficiency, %: N/A 22.4 Pump Derating Derating Factor for Rate, %: 80.0 Derating Factor for Head, %: 80.0 Derating Factor for Power, %: 120.0 Housing Data

Stages

Hagedorn &

Hsg. # Hsg. Type Length, ft ** = Abrasion Resistant 100 CR** 14.80 100 CR** 14.80 100 CR** 14.80 100 CR** 14.80 Total 400 59.20 Net Stages in Pump: 652

# of 163 163 163 163 652

CABLE DATA Reda 375 87 - Double

Name Plate Power, HP: Plate Frequency, Hz: 60 Name Plate Voltage, Volts: Plate Current, Amps: 51.0

102.0

Name

1480.00

Name

Adjust for Motor Slip:Yes 45.3 Design Frequency, Hz: Operating Voltage, Volts: Operating Motor Load, HP: Operating Power Factor, frac: (@ Design Frequency) Operating Motor Load, : Operating Efficiency, %: Operating Speed, RPM: Velocity, ft/sec: 0.398

Operating Current,

Manufacturer: Reda Type: Redalead Size: 4 Cu Shape: Round Conductor Type: Solid Max. Cond. Temp., °F: 400.0 Cable Length, ft: 8900.00 Solve for: Surface Voltage Electric Cost, $/kWH: 0.00

Amps:

57.0 1406.00 78.6 0.670 81.13 77.58 3298

Design Freq.

Fluid

Well Fluid Temperature, °F: 145.8 Speed Increase Heating, °F: 0.0 Skin Temperature Rise, °F: 48.5 Harmonic Heating due to VSD, °F: 4.3 Avg. Winding Temp. Rise over Skin, °F: 25.2 Total Winding Temp., °F: 219.6 If Sine Wave Filter is used in VSD operation, Harmonic Heating is zero. Catalog

Actual

Total Stages 652 652 Slip Stages 0 0 Total Dynamic Head (TDH), ft 7515.67 7401.86 Surface Rate (O+W), Bbl/D 352.21 Avg. Pump Rate (O+G+W), Bbl/D 385.33 Pump Intake Pressure, psig 768.1 Operating Power, HP 75.3 75.0 Min. Efficiency, % 22.4 24.6 Operating Speed, RPM 3325

Volts

348.75 389.16

Volts

787.7

Volts

3297

Frequency, Hz 57 Conductor Temp., °F 169.7 Max. Allowable Amps, Amps 148.0 Amperage, Amps 45.3 Kilovolt Amper, KVA 127.3 Kilowatts, KW 85.3 Kilowatts, $/mo 0 Surface Voltage, Volts 1622.1 Voltage Drop @ 68.0 °F, Volts 183.8 Voltage Drop @ 150.0 °F BHT, 216.1 Kilowatt Loss, KW 11.3 Cost of Voltage Loss, $/mo 0 Required Motor Voltage, Volts 1406.0 Downhole Voltage at Motor, 1406.0 In-rush Motor Voltage Drop, 864.3 Motor Startup Voltage, Volts 757.8 Startup/Operating Ratio, ratio 0.5

WELL 1045 GENERAL DESCRIPTION

WELLBORE DATA

Company Name: Schlumberger Well Name: 1045 Field Name: Kurovdag Reservoir Name: PS 08 Analyst: Eduardo Escobar D. Calculation Type: Rigorous Design Location: Comments: AN550 Date: 06/03/2003

OD

PUMP DATA 1

MOTOR DATA

Manufacturer: Series: Model:

Reda 338 AN550

in

Number of Stages, : 145 Stages with Free Gas: 145 Additional Stages due to Gas:

0

Viscosity Correction Factors User Entered Rate: 1.000 No Head: 1.000 No Power: 1.000 No Efficiency: 1.000 Design 145 Stages Total Dynamic Head (TDH), ft: 667.40 573.35 Surface Rate (O+W), Bbl/D: 490.00 485.55 Avg. Pump Rate (O+G+W), Bbl/D: N/A 606.93 Pump Intake Pressure, psig: 2064.3 2088.2 Operating Power, HP: N/A 8.9 Min. Efficiency, %: N/A 29.8 Pump Derating Derating Factor for Rate, %: Derating Factor for Head, %: Derating Factor for Power, %:

92.0 92.0 110.0

Housing Data ** = Abrasion Resistant 13.30

145

13.30 0 145

145

ID

Rough.

Bottom MD

No. ft

in ft

lb/ft

in

2.875

6.50

2.441

Tubing 1 0.0006500 8217.00

Casing 1 5.500 15.50 0.0006500 9650.00 0.00 Pump Depth, ft: 8217.00 Top of Perfs. or Datum Pt. (MD), ft: 9527.00 Reservoir Temperature, °F: 150.0 Wellhead Temperature, °F: 70.0

Manufacturer: Series: Type:

Minimum Recommended Rate, Bbl/D: 306.89** Maximum Recommended Rate, Bbl/D: 537.06** Rate at Peak Efficiency, Bbl/D: 467.50** Power at Peak Efficiency, HP: 10.8** Frequency, Hz: 50.0 ** = Corrected for Frequency & Viscosity

90 CR** Total 90 Blank Stages Input: Net Stages in Pump:

Wt Top MD

SEAL DATA Manufacturer: Reda Series: 325-375 Bearing Type: Chamber Selection: HTM

325 STD PF SB

Bearing Cap., lb: 963.1 Maximum Thrust Load, lb: 513.5 Power Consumption, HP: 0.3

4.950

CABLE DATA Reda 375 87 - Single

Name Plate Power, HP: Plate Frequency, Hz: 60 Name Plate Voltage, Volts: Plate Current, Amps: 25.0 Adjust for Motor Slip:Yes 17.7 Design Frequency, Hz: Operating Voltage, Volts: Operating Motor Load, HP: Operating Power Factor, frac: (@ Design Frequency) Operating Motor Load, : Operating Efficiency, %: Operating Speed, RPM: Velocity, ft/sec: 0.554

25.5

Name

760.00

Name

Manufacturer: Reda Type: Redalead Size: 4 Cu Shape: Round Conductor Type: Solid Max. Cond. Temp., °F: 400.0 Cable Length, ft: 8317.00

Operating Current,

Solve for: Surface Voltage Electric Cost, $/kWH: 0.00

Amps:

50.0 633.33 11.3 0.548 53.01 71.44 2919

Design Freq.

Fluid

Well Fluid Temperature, °F: 139.0 Speed Increase Heating, °F: 0.0 Skin Temperature Rise, °F: 22.6 Harmonic Heating due to VSD, °F: 4.3 Avg. Winding Temp. Rise over Skin, °F: 25.0 Total Winding Temp., °F: 186.6 If Sine Wave Filter is used in VSD operation, Harmonic Heating is zero. Catalog

Actual

Total Stages 145 145 Slip Stages 0 0 Total Dynamic Head (TDH), ft 573.35 Surface Rate (O+W), Bbl/D 485.55 Avg. Pump Rate (O+G+W), Bbl/D 607.05 Pump Intake Pressure, psig 2088.2 Operating Power, HP 8.9 9.0 Min. Efficiency, % 29.8 23.2 Operating Speed, RPM 2916

Volts

577.50 485.64 606.93 Volts 2087.7 Volts 2918

Frequency, Hz 50 Conductor Temp., °F 142.6 Max. Allowable Amps, Amps 150.0 Amperage, Amps 17.7 Kilovolt Amper, KVA 21.9 Kilowatts, KW 12.0 Kilowatts, $/mo 0 Surface Voltage, Volts 712.3 Voltage Drop @ 68.0 °F, Volts 67.2 Voltage Drop @ 150.0 °F BHT, 79.0 Kilowatt Loss, KW 1.3 Cost of Voltage Loss, $/mo 0 Required Motor Voltage, Volts 633.3 Downhole Voltage at Motor, 633.3 In-rush Motor Voltage Drop, 316.0 Motor Startup Voltage, Volts 396.4 Startup/Operating Ratio, ratio 0.6

WELL 1030 GENERAL DESCRIPTION

WELLBORE DATA

Company Name: Schlumberger Well Name: 1030 Field Name: Kurovdag Reservoir Name: PS 01/02 Analyst: Eduardo Escobar Calculation Type: Rigorous Design Location: Comments: Date: 06/03/2003

OD

Wt Top MD

SEAL DATA ID

Rough.

Bottom MD

No. ft

in ft

lb/ft

in

Tubing 1 0.0006500 8700.00

2.875

6.50

2.441

Casing 1 0.0006500 9850.00

5.500 0.00

in

15.50

Manufacturer: Reda Series: 325-375 Bearing Type: Chamber Selection: HTM HL

325 HL PF SB

Bearing Cap., lb: 3285.9 Power Consumption, HP: 0.1

4.950

Pump Depth, ft: 8700.00 Top of Perfs. or Datum Pt. (MD), ft: 9257.00 Reservoir Temperature, °F: 150.0 Wellhead Temperature, °F: 70.0 PUMP DATA 1 Manufacturer: Series: Model:

MOTOR DATA Reda 338 A400

Manufacturer: Series: Type:

Minimum Recommended Rate, Bbl/D: 182.59** Maximum Recommended Rate, Bbl/D: 456.48** Rate at Peak Efficiency, Bbl/D: 396.00** Power at Peak Efficiency, HP: 37.1** Frequency, Hz: 60.0 ** = Corrected for Frequency & Viscosity Number of Stages, : 363 Stages with Free Gas: 363 Additional Stages due to Gas:

0

Viscosity Correction Factors User Entered Rate: 1.000 Head: 1.000 Power: 1.000 Efficiency: 1.000 Design

No No No

Total Dynamic Head (TDH), ft: 5239.77 5235.88 Surface Rate (O+W), Bbl/D: 360.00 359.67 Avg. Pump Rate (O+G+W), Bbl/D: N/A 379.38 Pump Intake Pressure, psig: 1135.9 1137.6 Operating Power, HP: N/A 39.1 Min. Efficiency, %: N/A 35.6 Pump Derating

Housing Data NO HOUSINGS SELECTED

Reda 375 87 - Double

Name Plate Power, HP: Plate Frequency, Hz: 60 Name Plate Voltage, Volts: Plate Current, Amps: 30.0 Adjust for Motor Slip:Yes 27.2 Design Frequency, Hz: Operating Voltage, Volts: Operating Motor Load, HP: Operating Power Factor, frac: (@ Design Frequency) Operating Motor Load, : Operating Efficiency, %: Operating Speed, RPM: Velocity, ft/sec: 0.410

51.0

Name

1260.00

Name

92.0 92.0 110.0

Manufacturer: Type: Size: Shape: Round Conductor Type: Solid Max. Cond. Temp., °F: 0.0 Cable Length, ft: 8800.00

Operating Current,

Solve for: Surface Voltage Electric Cost, $/kWH: 0.00

Amps:

60.0 1260.00 42.7 0.678 83.72 77.99 3473

Well Fluid Temperature, °F: 145.2 Increase Heating, °F: 0.0 Skin Temperature Rise, °F: 25.4 Harmonic Heating due to VSD, °F: Avg. Winding Temp. Rise over Skin, °F: Total Winding Temp., °F: 196.3

363 Stages

Derating Factor for Rate, %: Derating Factor for Head, %: Derating Factor for Power, %:

CABLE DATA

Catalog

Design Freq.

Fluid

Speed

0.0 25.7

Actual

Total Stages 363 371 Slip Stages 0 8 Total Dynamic Head (TDH), ft 5235.88 5235.82 Surface Rate (O+W), Bbl/D 359.67 Avg. Pump Rate (O+G+W), Bbl/D 379.27 Pump Intake Pressure, psig 1137.6 Operating Power, HP 39.1 39.1 Min. Efficiency, % 35.6 35.6 Operating Speed, RPM 3500

Volts

359.56 379.38 1138.2

Volts Volts

3473

Frequency, Hz 60 Conductor Temp., °F 0.0 Max. Allowable Amps, Amps 0.0 Amperage, Amps 27.2 Kilovolt Amper, KVA 0.0 Kilowatts, KW 0.0 Kilowatts, $/mo 0 Surface Voltage, Volts 0.0 Voltage Drop @ 68.0 °F, Volts 0.0 Voltage Drop @ 150.0 °F BHT, 0.0 Kilowatt Loss, KW 0.0 Cost of Voltage Loss, $/mo 0 Required Motor Voltage, Volts 0.0 Downhole Voltage at Motor, 0.0 In-rush Motor Voltage Drop, 0.0 Motor Startup Voltage, Volts 0.0 Startup/Operating Ratio, ratio 0.0

WELL 751 GENERAL DESCRIPTION

WELLBORE DATA

Company Name: Schlumberger Well Name: 751 Field Name: Kurovdag Reservoir Name: PS 05 Analyst: Eduardo Escobar D. Calculation Type: Rigorous Design Location: Comments: Date: 06/03/2003

OD

Wt Top MD

SEAL DATA ID

Rough.

Bottom MD

No. ft

in ft

lb/ft

in

Tubing 1 0.0006500 6100.00

2.875

6.50

2.441

Casing 1 0.0006500 9250.00

5.500 0.00

in

15.50

Manufacturer: Reda Series: 325-375 Bearing Type: Chamber Selection: HTM

Bearing Cap., lb: 963.1 Operating Thrust Load, lb: 669.3 Maximum Thrust Load, lb: 1038.6 Power Consumption, HP: 0.3

4.950

Pump Depth, ft: 6100.00 Top of Perfs. or Datum Pt. (MD), ft: 6583.00 Reservoir Temperature, °F: 150.0 Wellhead Temperature, °F: 70.0 PUMP DATA 1 Manufacturer: Series: Model:

MOTOR DATA Manufacturer: Series: Type:

Reda 400 DN440

Minimum Recommended Rate, Bbl/D: 75.93** Maximum Recommended Rate, Bbl/D: 417.63** Rate at Peak Efficiency, Bbl/D: 366.67** Power at Peak Efficiency, HP: 30.8** Frequency, Hz: 50.0 Number of Stages, : 429 Stages with Free Gas: 429 Additional Stages due to Gas:

0

Viscosity Correction Factors User Entered Rate: 1.000 Head: 1.000 Power: 1.000 Efficiency: 1.000 Design

No No No

429 Stages

Total Dynamic Head (TDH), ft: 5655.92 5606.11 Surface Rate (O+W), Bbl/D: 260.00 258.22 Avg. Pump Rate (O+G+W), Bbl/D: N/A 310.59 Pump Intake Pressure, psig: 557.9 566.0 Operating Power, HP: N/A 30.2 Min. Efficiency, %: N/A 33.1 Pump Derating Derating Factor for Rate, %: Derating Factor for Head, %: Derating Factor for Power, %: Housing Data 13.40 161 90 FL 13.40 60 FL 9.20 Total 240 36.00 Blank Stages Input: 0 Net Stages in Pump: 429

92.0 92.0 115.0

161 107 429

325 STD PF SB

CABLE DATA Reda 375 87 - Double

Name Plate Power, HP: Plate Frequency, Hz: 60 Name Plate Voltage, Volts: Plate Current, Amps: 30.0 Adjust for Motor Slip:Yes 25.3 Design Frequency, Hz: Operating Voltage, Volts: Operating Motor Load, HP: Operating Power Factor, frac: (@ Design Frequency) Operating Motor Load, : Operating Efficiency, %: Operating Speed, RPM: Velocity, ft/sec: 0.291

51.0

Name

1260.00

Name

Manufacturer: Reda Type: Redalead Size: 4 Cu Shape: Round Conductor Type: Solid Max. Cond. Temp., °F: 400.0 Cable Length, ft: 6200.00

Operating Current,

Amps:

Solve for: Surface Voltage Electric Cost, $/kWH: 0.00

50.0 1050.00 31.5 0.646 74.09 76.41 2889

Design Freq.

Fluid

Well Fluid Temperature, °F: 144.1 Speed Increase Heating, °F: 0.0 Skin Temperature Rise, °F: 37.4 Harmonic Heating due to VSD, °F: 4.3 Avg. Winding Temp. Rise over Skin, °F: 25.0 Total Winding Temp., °F: 206.5 If Sine Wave Filter is used in VSD operation, Harmonic Heating is zero. Catalog

Actual Volts

Total Stages 429 429 Slip Stages 0 0 Total Dynamic Head (TDH), ft 5606.11 5517.14 Surface Rate (O+W), Bbl/D 258.22 Avg. Pump Rate (O+G+W), Bbl/D 306.76 Pump Intake Pressure, psig 566.0 Operating Power, HP 30.2 29.1 Min. Efficiency, % 33.1 35.8 Operating Speed, RPM 2916

255.04 310.59 Volts 580.5 Volts 2888

Frequency, Hz 50 Conductor Temp., °F 151.6 Max. Allowable Amps, Amps 148.5 Amperage, Amps 25.3 Kilovolt Amper, KVA 49.8 Kilowatts, KW 32.1 Kilowatts, $/mo 0 Surface Voltage, Volts 1133.8 Voltage Drop @ 68.0 °F, Volts 71.3 Voltage Drop @ 150.0 °F BHT, 83.8 Kilowatt Loss, KW 2.4 Cost of Voltage Loss, $/mo 0 Required Motor Voltage, Volts 1050.0 Downhole Voltage at Motor, 1050.0 In-rush Motor Voltage Drop, 335.1 Motor Startup Voltage, Volts 798.7 Startup/Operating Ratio, ratio 0.8

WELL 1355

1355.sp6

Pump Performance (TDH) Reda 338 A400 / 624 Stgs / 52.0 Hz 20000

TDH, ft

15000

10000

5000

0 0

100

200

300

400

500

600

700

Rate, Bbl/D Pump Curve at 52.0 Hz Pump Curve at 57.0 Hz Well System Curve

Pump Curve at 42.0 Hz Pump Curve at 62.0 Hz Design Point

Pump Curve at 47.0 Hz Min-Max Optimum Rate Reg: Authorized User - Schlumberger

1355.sp6

Inflow Performance 1355 4000

Pressure, psig

3000

2000

1000

0 0

100

200

300

400

500

Rate, Bbl/D Inflow @ Perfs

Inflow @ Pump

Design Point

Reg: Authorized User - Schlumberger

WELL 1220

1220.sp6

Pump Performance (TDH) Reda 338 A400 / 624 Stgs / 55.0 Hz 20000

TDH, ft

15000

10000

5000

0 0

100

200

300

400

500

600

700

Rate, Bbl/D Pump Curve at 55.0 Hz Pump Curve at 60.0 Hz Well System Curve

Pump Curve at 45.0 Hz Pump Curve at 65.0 Hz Design Point

Pump Curve at 50.0 Hz Min-Max Optimum Rate Reg: Authorized User - Schlumberger

1220.sp6

Inflow Performance 1220 4000

Pressure, psig

3000

2000

1000

0 0

100

200

300

400

500

Rate, Bbl/D Inflow @ Perfs

Inflow @ Pump

Design Point

Reg: Authorized User - Schlumberger

WELL 1126

1126.sp6

Pump Performance (TDH) Reda 338 AN550 / 652 Stgs / 57.0 Hz 16000 14000 12000

TDH, ft

10000 8000 6000 4000 2000 0 0

100

200

300

400

500

600

700

800

Rate, Bbl/D Pump Curve at 57.0 Hz Pump Curve at 62.0 Hz Well System Curve

Pump Curve at 47.0 Hz Pump Curve at 67.0 Hz Design Point

Pump Curve at 52.0 Hz Min-Max Optimum Rate Reg: Authorized User - Schlumberger

1126.sp6

Inflow Performance 1126 4000

Pressure, psig

3000

2000

1000

0 0

100

200

300

400

500

600

Rate, Bbl/D Inflow @ Perfs

Inflow @ Pump

Design Point

Reg: Authorized User - Schlumberger

WELL 1045

1045.sp6

Inflow Performance 1045 6000

5000

Pressure, psig

4000

3000

2000

1000

0 0

100

200

300

400

500

600

700

800

900

1000

Rate, Bbl/D Inflow @ Perfs , Case 2

Inflow @ Perfs , Case 3

Inflow @ Pump , Case 3

Design Point

Inflow @ Pump , Case 2 Reg: Authorized User - Schlumberger

1045.sp6

Pump Performance (TDH) Reda 338 AN550 / 145 Stgs / 50.0 Hz 6000

4000

TDH, ft

2000

0

-2000

-4000

-6000

-8000 0

100

200

300

400

500

600

700

800

900

Rate, Bbl/D Pump Curve at 50.0 Hz Pump Curve at 45.0 Hz Pump Curve at 60.0 Hz Well System Curve(Truncated)

Pump Curve at 40.0 Hz Pump Curve at 55.0 Hz Min-Max Optimum Rate Design Point

Reg: Authorized User - Schlumberger

WELL 1030

1030.sp6

Pump Performance (TDH) Reda 338 A400 / 371 Stgs / 60.0 Hz 10000 9000 8000 7000

TDH, ft

6000 5000 4000 3000 2000 1000 0 0

100

200

300

400

500

600

700

800

Rate, Bbl/D Pump Curve at 60.0 Hz Pump Curve at 65.0 Hz Well System Curve

Pump Curve at 50.0 Hz Pump Curve at 70.0 Hz Design Point

Pump Curve at 55.0 Hz Min-Max Optimum Rate Reg: Authorized User - Schlumberger

1030.sp6

Inflow Performance 1030 4000

Pressure, psig

3000

2000

1000

0 0

100

200

300

400

500

600

700

Rate, Bbl/D Inflow @ Perfs

Inflow @ Pump

Design Point

Reg: Authorized User - Schlumberger

WELL 751

751.sp6

Inflow Performance 751 2500

Pressure, psig

2000

1500

1000

500

0 0

100

200

300

400

500

Rate, Bbl/D Inflow @ Perfs

Inflow @ Pump

Design Point

Reg: Authorized User - Schlumberger

751.sp6

Pump Performance (TDH) Reda 400 DN440 / 429 Stgs / 50.0 Hz 12000

10000

TDH, ft

8000

6000

4000

2000

0 0

100

200

300

400

500

600

700

Rate, Bbl/D Pump Curve at 50.0 Hz Pump Curve at 55.0 Hz Well System Curve

Pump Curve at 40.0 Hz Pump Curve at 60.0 Hz Design Point

Pump Curve at 45.0 Hz Min-Max Optimum Rate Reg: Authorized User - Schlumberger