John Stachowiak, Doug Hebert Weatherford International New Sand Tolerant Pump Technology for Increased Run life in Sandy Wells Title slide Keep the title brief and to one line? The second line (in smaller type style) is for the date of the presentation – depending on your presentation, you may also need to include Location and/or Presenter’s name/s and Job title if needed – as a such a second line may be used for these purposes. Do not include unnecessary information in your presentation title – starting off with clear and simple messages will set the style and focus the audience for what is to follow. John Stachowiak, Doug Hebert Weatherford International

2015 Sucker Rod Pumping Workshop Topics of Discussion Conventional pump geometry and operation Damaging effects of sand in a pump New Sand Tolerant Pump (STP) technology geometry and operation Testing overview Testing results Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop

Pump Geometry and Operation Slide 3 Pump Geometry and Operation Tubing Conventional insert pump Barrel Plunger Travelling valve Standing valve Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 3

Pump Geometry and Operation - Upstroke Slide 4 Pump Geometry and Operation - Upstroke Barrel High Pressure Plunger Upstroke Travelling valve Low Pressure Standing valve Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 4

Pump Geometry and Operation - Upstroke Slide 5 Slide 5 Pump Geometry and Operation - Upstroke Slippage fluid Slippage fluid High Pressure Upstroke Barrel Low Pressure Plunger Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 5

Pump Geometry and Operation - Upstroke Slide 6 Pump Geometry and Operation - Upstroke Pump Slippage fluid Necessary for lubrication between the plunger and barrel Slippage clearance is inversely proportional to the pump efficiency Should be clean for greater pump life Slippage fluid Slippage fluid Barrel Plunger Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 6

Pump Geometry and Operation - Downstroke Slide 7 Pump Geometry and Operation - Downstroke High Pressure Barrel Plunger Pressure Balanced Downstroke Travelling valve High Pressure Standing valve Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 7

Pump Geometry and Operation - Downstroke Slide 8 Pump Geometry and Operation - Downstroke Slippage fluid on downstroke? Due to the pressure being equalized, the slippage fluid is minimal Barrel Plunger Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 8

Pump Geometry and Operation - Downstroke Slide 9 Pump Geometry and Operation - Downstroke Barrel What happens when sand is present in the fluid on the downstroke? Plunger Downstroke Travelling valve Sand particle Standing valve Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 9

Pump Geometry and Operation - Downstroke Slide 10 Pump Geometry and Operation - Downstroke On the downstroke, the plunger is driven through the sandy fluid, allowing the sand particles to move above the plunger leading edge Plunger leading edge Barrel Sand particle Plunger Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 10

Pump Geometry and Operation - Upstroke Slide 11 Pump Geometry and Operation - Upstroke High Pressure Barrel Plunger What happens when sand is present in the fluid on the upstroke? upstroke Travelling valve Low Pressure Standing valve Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 11

Pump Geometry and Operation – Upstroke Slide 12 Pump Geometry and Operation – Upstroke On the upstroke, the differential pressure drives the sand-laden slippage fluid between the plunger and barrel. Slippage fluid Slippage fluid Barrel Plunger leading edge Sand particle Plunger Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 12

Pump Geometry and Operation - Upstroke Slide 13 Pump Geometry and Operation - Upstroke …a closer look Slippage fluid Slippage fluid Barrel Plunger leading edge Sand particle Plunger Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 13

Pump Geometry and Operation - Upstroke Slide 14 Pump Geometry and Operation - Upstroke …a closer look Sand particle diameter Smaller sand particles can pass through the plunger/barrel interface easily with little to no damage. Plunger/barrel clearance Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 14

Pump Geometry and Operation - Upstroke Slide 15 Pump Geometry and Operation - Upstroke …a closer look Sand particle diameter For maximum plunger and barrel life: Plunger/barrel clearance < Sand particle diameter Plunger/barrel radial clearance Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 15

Pump Geometry and Operation - Upstroke Slide 16 Pump Geometry and Operation - Upstroke Sand particles typically comes from two sources: Formation sand Frac sand Typical properties: Size range: .0004” (talc) - .019” Hardness: Up to 7 Moh’s (approx 70 Rc) Two-Column Format Not all sand particles are created equal! Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 16

Pump Operation With Sand - Upstroke Slide 17 Pump Operation With Sand - Upstroke When a larger particle cannot easily pass by the plunger it becomes lodged. Slippage fluid Slippage fluid Barrel Large sand particle Plunger Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 17

Pump Operation With Sand - Upstroke Slide 18 Pump Operation With Sand - Upstroke Slippage fluid hydrostatic load The upward plunger motion along with the hydrostatic load assists to drive the hard sand particle between the plunger and barrel, causing a small groove. A groove is created in plunger or barrel Plunger motion Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 18

Pump Operation With Sand - Upstroke Slide 19 Pump Operation With Sand - Upstroke Slippage fluid hydrostatic load On the next upstroke, more large particles can now follow the same path, creating a longer groove. Groove Length Plunger motion Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 19

Pump Operation With Sand – Plunger Grooving Slide 20 Pump Operation With Sand – Plunger Grooving This process continues until the groove is extended the entire length of the plunger and/or the swept length of the barrel Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 20

Pump Operation With Sand – Plunger grooving Slide 21 Pump Operation With Sand – Plunger grooving As more grooves are created, the plunger becomes extremely inefficient as more fluid is lost from slippage on the upstroke This process continues until the groove is extended the entire length of the plunger and/or the length of the swept length of the barrel As more grooves are created, the plunger becomes extremely inefficient as more fluid is lost from slippage on the upstroke Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 21

New Sand Tolerant Pump (STP) Slide 22 New Sand Tolerant Pump (STP) Overview Tubing Sand control region New Sand Tolerant Pump (STP) Technology With Integral Screen Barrel Plunger Travelling valve Standing valve Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 22

New Sand Tolerant Pump (STP) Slide 23 New Sand Tolerant Pump (STP) Overview Wiping Rings Ring Mandrel Filter Screen Production Plunger Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 23

New Sand Tolerant Pump (STP) Slide 24 New Sand Tolerant Pump (STP) Operation - Upstroke High Pressure Barrel Plunger Upstroke Travelling valve Low Pressure Standing valve Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 24

New Sand Tolerant Pump (STP) Slide 25 New Sand Tolerant Pump (STP) Operation - Upstroke On the upstroke, the wiper rings are pressure balanced. The wiper rings do not see the differential hydrostatic load – No lifting edge High Pressure Wiper rings Filter Screen High Pressure Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 25

New Sand Tolerant Pump (STP) Slide 26 New Sand Tolerant Pump (STP) Operation - Upstroke Upstroke Slippage fluid Slippage fluid Wiper rings act as fluid/sand barrier All of the slippage fluid is forced through the screen Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 26

New Sand Tolerant Pump (STP) Slide 27 New Sand Tolerant Pump (STP) Operation - Upstroke Upstroke Screen The screen is sized to only allow particles to pass through that are smaller than the radial clearance “fit” of the production plunger Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 27

New Sand Tolerant Pump (STP) Slide 28 New Sand Tolerant Pump (STP) Operation - Upstroke Upstroke At the top of the plunger upstroke, there may be many particles that have accumulated on the inside of the screen. Particles trapped by screen Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 28

New Sand Tolerant Pump (STP) Operation - Downstroke Slide 29 New Sand Tolerant Pump (STP) Operation - Downstroke On the downstroke…. High Pressure Barrel Plunger The pressure is equalized above and below the plunger Travelling valve High Pressure Standing valve Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 29

New Sand Tolerant Pump (STP) Operation - Downstroke Slide 30 New Sand Tolerant Pump (STP) Operation - Downstroke On the downstroke…. …The flow of slippage fluid stops Trapped Particles become loose No flow across screen Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 30

New Sand Tolerant Pump (STP) Operation - Downstroke Slide 31 New Sand Tolerant Pump (STP) Operation - Downstroke Downstroke The fluid rushes up through the inside of the plunger assembly, and washes the screen clean Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 31

Testing the Sand Tolerant Pump (STP) Concept Slide 32 New Sand Tolerant Pump (STP) Testing Testing the Sand Tolerant Pump (STP) Concept Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 32

New Sand Tolerant Pump (STP) Slide 33 New Sand Tolerant Pump (STP) Testing Parameters To test the technology, the following insert-style pumps were selected: 1 ¼” bore 1 ½” bore 1 ¾” bore 2” bore Wiping Rings Ring Mandrel Filter Screen Production Plunger Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 33

New Sand Tolerant Pump (STP) Slide 34 New Sand Tolerant Pump (STP) Testing Parameters Wells that produce sand resulting in short runtimes. Neither of the two previous pump installations using conventional pumps obtained more than 365 days of run life. 56 “problem” wells were chosen for testing. The problem wells were selected based on the following criteria: Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 34

New Sand Tolerant Pump (STP) Slide 35 New Sand Tolerant Pump (STP) Testing Parameters The properties of the well and previous installations were as follows: Fluid composition- Varied from light to heavy, 30-95% water cut. Pump depth – 3000-4500 ft with a few at 9000 ft Stroke rate 6-7 strokes per minute Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 35

New Sand Tolerant Pump (STP) Slide 36 New Sand Tolerant Pump (STP) Testing Parameters Out of the 56 wells, the following quantities of the Sand Tolerant Pumps were installed 1 ¼” bore – 24 installations 1 ½” bore – 17 installations 1 ¾” bore – 10 installations 2” bore – 5 installations Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 36

New Sand Tolerant Pump (STP) Slide 37 New Sand Tolerant Pump (STP) Testing Parameters **Important note: The data collected from the “problem wells” was based solely on run time between pulls. The actual failure mode was not recorded and may have been one of the following Severe plunger/barrel sand cut or erosion Sand filled to the pump intake Sanded-in rod string Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 37

New Sand Tolerant Pump (STP) Slide 38 New Sand Tolerant Pump (STP) Testing Parameters Severe plunger/barrel sand cut or erosion Sand filled to the pump intake Sanded-in rod string This technology should have a direct impact on this failure mode This technology should have an indirect impact on these failure modes Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 38

Testing Results – 1 ¼” Bore New Technology STP Slide 39 Testing Results – 1 ¼” Bore New Technology STP STP (6.2X Run life) Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 39

Testing Results – 1 1/2” Bore New Technology STP Slide 40 Testing Results – 1 1/2” Bore New Technology STP STP (2.9X Run life) Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 40

Testing Results – 1 3/4” Bore New Technology STP Slide 41 Testing Results – 1 3/4” Bore New Technology STP STP (8.9X Run life) Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 41

Testing Results – 2” Bore New Technology STP Slide 42 Testing Results – 2” Bore New Technology STP STP (3.8X run life) Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 42

Average of two Previous Conventional Runtime (All Wells) New Technology STP Vs Average of two Previous Conventional Runtime (All Wells) Slide 43 (3.9x Run life) (5.5x Run life) Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 43

Best Conventional Runtime (All Wells) New Technology STP Vs Best Conventional Runtime (All Wells) Slide 44 (3.9x Run life) STP Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 44

New Technology STP Performance Slide 45 New Technology STP Performance 450% average increase when compared to the two previous averaged conventional pump runtimes. 293% average increase when compared to the best of the two previous conventional pump runtimes. 30 out of the 56 new technology pumps installed continue to run as of 11/11/2014 Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 45

New Technology STP Performance Slide 46 New Technology STP Performance Typically a run life that is less than 30 days indicates wellbore issues rather than pump sand damage. Wellbore issues may include Wellbore not cleaned out before pump installation Perforations covered by sand (no inflow) Sand filled to the pump intake Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 46

Best Conventional Runtime (All Wells) New Technology STP Vs Best Conventional Runtime (All Wells) Slide 47 Therefore, the previous conventional pump runs of less than 30 days were eliminated and the data was recalculated Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 47

Best Conventional Runtime (greater than 30 days) New Technology STP Vs Best Conventional Runtime (greater than 30 days) Slide 48 (2.1 X Run life) STP Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 48

New Technology STP Pump Performance Update Slide 49 New Technology STP Pump Performance Update …..Update as of 6/15/15 Out of these 26 wells that were still running on 11/11/14 14 are still running Average run-life is 572 days The maximum run life to-date is 781 days 43% (24 out of 56) of the Sand Tolerant Pumps achieved a minimum run life of 383 days. This is greater than the best conventional run-life (out of all 112 installations.) Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop 49

2015 Sucker Rod Pumping Workshop Copyright Rights to this presentation are owned by the company(ies) and/or author(s) listed on the title page. By submitting this presentation to the Sucker Rod Pumping Workshop, they grant to the Workshop, the Artificial Lift Research and Development Council (ALRDC), and the Southwestern Petroleum Short Course (SWPSC), rights to: Display the presentation at the Workshop. Place it on the www.alrdc.com web site, with access to the site to be as directed by the Workshop Steering Committee. Place it on a CD for distribution and/or sale as directed by the Workshop Steering Committee. Other use of this presentation is prohibited without the expressed written permission of the author(s). The owner company(ies) and/or author(s) may publish this material in other journals or magazines if they refer to the Sucker Rod Pumping Workshop where it was first presented. Sept. 15 – 18, 2015 2015 Sucker Rod Pumping Workshop

2015 Sucker Rod Pumping Workshop Disclaimer The Artificial Lift Research and Development Council and its officers and trustees, and the Sucker Rod Pumping Workshop Steering Committee members, and their supporting organizations and companies (here-in-after referred to as the Sponsoring Organizations), and the author(s) of this Technical Presentation or Continuing Education Training Course and their company(ies), provide this presentation and/or training material at the Sucker Rod Pumping Workshop "as is" without any warranty of any kind, express or implied, as to the accuracy of the information or the products or services referred to by any presenter (in so far as such warranties may be excluded under any relevant law) and these members and their companies will not be liable for unlawful actions and any losses or damage that may result from use of any presentation as a consequence of any inaccuracies in, or any omission from, the information which therein may be contained. The views, opinions, and conclusions expressed in these presentations and/or training materials are those of the author and not necessarily those of the Sponsoring Organizations. The author is solely responsible for the content of the materials. The Sponsoring Organizations cannot and do not warrant the accuracy of these documents beyond the source documents, although we do make every attempt to work from authoritative sources. The Sponsoring Organizations provide these presentations and/or training materials as a service. The Sponsoring Organizations make no representations or warranties, express or implied, with respect to the presentations and/or training materials, or any part thereof, including any warrantees of title, non-infringement of copyright or patent rights of others, merchantability, or fitness or suitability for any purpose. Sept. 15 - 18, 2015 2015 Sucker Rod Pumping Workshop